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199-093
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 02-27A Mill CIBP, Install Tbg Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 199-093 50-029-21994-01-00 11860 Conductor Intermediate Scab Liner Liner Liner 8983 80 9264 4706 3177 11733 20" 7-5/8" 5-1/2" 3-1/2" 8977 29 - 109 27 - 9291 3984 - 8690 8683 - 11860 29 - 109 27 - 8439 3981 - 7959 7953 - 8983 11733 470 4790 6280 10530 none 1490 6890 7740 10160 8986 - 11745 3-1/2" 9.2# 13Cr85 25 - 8700 8202 - 8977 Structural 3-1/2" Baker SABL-3 , 8614 , 7896 No SSSV 8614 , 8674 7896 , 7946 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY / PUT RIVER OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028308 25-7963 345 422 14986 16815 19 23 1938 91 343 381 N/A 13b. Pools active after work:PRUDHOE BAY 4-1/2" Baker S-3 Perm , 8674 , 7946 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 10:17 am, Apr 02, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.29 18:38:08 - 08'00' Bo York (1248) DSR-4/12/24 RBDMS JSB 040424 WCB 2024-07-09 ACTIVITYDATE SUMMARY 9/22/2023 LRS CTU #1 - 1.50" Blue Coil Job objective: Mill CIBP MIRU. RIH w/ YJ Motor and junk mill (2.59" OD). Tag fill at 8970'. Cleanout to 9870' pumping gel sweeps. Circulate bottoms up. ***Continue on 09/23/23*** 9/23/2023 LRS CTU #1 - 1.50" Blue Coil Job objective: Mill CIBP Mill at 9870' and unable to get stall.. POOH to inspect tools. Metal pieces in water courses and cutting structure on mill face warn off. RIH w/ Venturi Burnshoe hard tag @ 9857' Attempt to burn over, stall/bit stuck a couple times. POOH to inspect tools. Recovered mostly sand, cement/mud and chuck of rubber element. RIH with 2.60' 4- bld junk mill. Mill at 9875' instant stalls. Time milled at 9875', just stacking weight with no more stalls. POOH to inspect mill. Cutting structure on mill worn down but had a ring on outer edge with even wear. ***Continued on 09/24/23*** 9/24/2023 LRS CTU #1 - 1.50" Blue Coil Job objective: Mill CIBP WELL CONTROL DRILL Make up 2.575" Venturi/BS and RIH. Set down in multiple spots. Hoover from 8590- 8900', kill pump and dry drift to 9868'. Unable to make any progress. POOH. Venturi packed w/ frac sand. Burnshoe has wear ring on outer edge of cutting structure. RIH w/ venturi 2.30" mule shoe. Tag hard @ 8565' CTM (X NIP @ 8587' MD). Unable to work passed jewelry. POOH. 1 quart - 1/2 gal of frac and formation sand in barrel. Make up 2.60" Venturi/BS and RIH. Tag at 9865' work burn shoe over area but not able to make any hole. Looks like still augering into sand. Pump gel pill and chase OOH. Recovered mud/cement and frac sand. Perform Weekly BOP test. Trim 50' of pipe. ***Continued on 09/25/23*** 9/25/2023 LRS CTU #1 - 1.50" Blue Coil Job objective: Mill CIBP Make up YJ milling BHA with 2.60" 3-bld junk mill and RIH. Set down at 8671'. Roll the pump past the jewelry. Dry tag at 9868'. Mill down to 9877" and had multiple stalls. Milled on at 9877' for several hours, did not make any footage. Occasional stalls. Chased gel pill OOH. Mill face was worn flat side of mill scarred. RBIH w/ motor/burnshoe. Dry tag 9875'. Mill plug and work down to TD at 11733' uncorrected. Pump gel pill sweeps off bottom and chase ooh. ***Continued on 09/26/23*** 9/26/2023 LRS CTU #1 - 1.50" Blue Coil Job objective: Mill CIBP Continue chasing gel sweeps ooh. Had a few overpulls in the liner. Wash across jewelry on way out. Plug not recovered. Make up 2.60" Venturi/burnshoe and RIH. Venturi down to 11733' and POOH. Displace well w/ diesel to 9000'. Core not recovered. RDMO ***Job Complete*** 10/16/2023 ***Well shut in on arrival*** Pressure test PCE to 200# LP-3,000# HP RIH W/ 1-7/16" CHD (1" FN), 1-11/16" Jars, Tractor, Mill (Max OD=2.75" (Mill), OAL=55', OAW=430#) Milled XN Nipple at 8687' from 2.635" to 2.75" ***Well left S/I*** Job continued 10/17/2023 Daily Report of Well Operations PBU 02-27A Tag fill at 8970'. Cleanout to 9870' j Make up YJ milling BHA with 2.60" 3-bld junk mill and RIH. Set down at 8671'. Rollgj the pump past the jewelry. Dry tag at 9868'. Mill down to 9877" and had multiplejyyg stalls. Milled on at 9877' for several hours, did not make any footage. Occasionalyg stalls. Chased gel pill OOH. Mill face was worn flat side of mill scarred. RBIH w/g motor/burnshoe. Dry tag 9875'. Mill plug and work down to TD at 11733' uncorrected. Daily Report of Well Operations PBU 02-27A 10/17/2023 Job continued from 10/16/2023 ***Well shut in on arrival*** Pressure test PCE to 200# LP-3000# HP RIH w/ 1-7/16" CHD (1" FN), 2 x 2" WB, 1-11/16" GR/CCL, 1-11/16" Jars, 2.70" Gauge ring (OAL=26' OAL, Max OD=2.7", OAW=260#) Drift to 9,270', Perfs seen at 9,010' RIH w/ 1-7/16" CHD (1" FN), 2 x 2" WB, 1-11/16" GR/CCL, Baker 10 setting tool, NS 350-272 13CR lower straddle (OAL=26' OAL, Max OD=2.7", OAW=330#) Set lower packer w/ ME set depth=9,015', CCL offset=13.5', CCL stop depth=9,001.5' ***Well left S/I*** 10/17/2023 T/I/O= 648/776/0 (PATCH TUBING/LINER) Assist E-Lined - Pumped 4.4 bbls of Crude to help push E-Line downhole. E-Line in control of well upon departure. FWHPs= 700/760/0 10/28/2023 ***WELL S/I ON ARRIVAL*** SET 37' MONO-PAK UPPER PATCH STUNG INTO LOWER PACKER @ 9,015' MD (upper section = 37' OAL) (Est top @ 8978' MD) SET 3 1/2" DREAM CATCHER AT 2200' MD ***WELL S/I ON DEPARTURE*** 11/1/2023 T/I/O = 1900/2010/0. Temp = 50°. Bleed IAP (eval TxIA). ALP = 1920 psi, SI @ CV. IA FL @ 3990' (4534' above sta #1 SO, 46 bbls). Bled IAP to 02-15 production from 2010 psi to 700 psi in 2 hrs. Monitored for 30 min. IAP increased 220 psi, IA FL inflowed to 2706' (5818' above sta #1 SO). Final WHPs = 1900/960/0. SV = C. WV, SSV, MV = O. IA, OA = OTG. 05:30 11/17/2023 T/I/O = SSV/1960/0+. Temp = SI°. Bleed IAP (eval TxIA). ALP = 1800 psi, SI @ CV. IA FL @ 7981' (543' above sta #1 SO). Bled IAP to 02-15 production (80') from 1960 psi to 520 psi in 2 hrs. Monitored for 30 min. IAP increased 250 psi, IA FL inconclusive. Final WHPs = SSV/770/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:00 11/21/2023 ***WELL S/I ON ARRIVAL*** (pull dream catcher) FUNCTION TEST WLV, BEGIN R/U SLICKLINE PCE ***CONT WSR ON 11/22/23*** 11/22/2023 ***CONT WSR FROM 11/21/23***(pull d. catcher, valve change) RAN 3-1/2" GR. SD @1,340' SLM. HYDRATES ON TOOL RAN 2.69" CENT, 1-3/4" S. BAILER. RECOVERED 1/4 CUP HYDRATES RAN 2.05" GAUGE CUTTER TO TAG HYDRATE @ 1553' SLM. ***DEPART LOCATION, LEAVE WELL SHUT IN*** 11/22/2023 TFS unit 4, Assist SL with hydrates pump as directed Pumped 6 BBLS of Neat to attempt to clear Tubing of ice. Slick Line in control of Well upon departure. FWHP= 2265/1400/0 psi 11/24/2023 T/I/O= 2308/1496/2 LRS Unit 76 (WELL THAW) Pumped .46 BBLS 60/40 dwn TBG. TBG locked up at 2500 PSI, Bled TBG down to 2028 PSI. Pumped 2 BBLS 60/40 followed by 360 BBLS 190*F Crude down the IA. Pumped 5 BBLS 60/40 followed by 63 BBLS 190*F Crude down the TBG for Hot Oil Treatment. Pumped 5 BBLS 60/40 followed by 113 BBLS Crude down the Flowline for Freeze Protect. FWHP's 1982/1658/41 DSO notified of well status. SET 37' MONO-PAK UPPER PATCH STUNG INTO LOWER PACKER @ 9,015' MD (upper section = 37' OAL) (Est top @ 8978' MD) Daily Report of Well Operations PBU 02-27A 11/26/2023 ***WELL S/I ON ARRIVAL*** DRIFT W/ 2.80" CENT. 2-1/2" SAMPLE BAILER TO 2,200' MD (NO HYDRATES) PULL 3-1/2" X-DREAM CATCHER @ 2,200' MD (EMPTY) ATTEMPT TO SET 2.70" WHIDDON ON XN (coil milled to 2.75" on 10/16/23, not on schematic) X-CATCHER SET ON PACKER @ 8,620' MD PULLED INTG-LGLV FROM ST#2 @ 7,524' MD PULLED INTG-LGLV FROM ST#3 @ 6,085' MD PULLED INTG-S/O FROM STA.# 1 @ 8,524' MD PULLED RK-DOME FROM STA.# 4 @ 3,800' MD SET RK-DOME (16/64"ports, tro 1500) IN STA.# 4 @ 3,800' MD ***CONTINUE 11/27/23*** 11/27/2023 ***CONTINUE FROM 11/26/23*** SET INTG-OGLV IN ST#3 @ 6,085' MD SET INTG-DGLV IN ST#2 @ 7,524' MD SET INTG-DGLV IN ST#1 @ 8,524' MD PULL X-CATCHER @ 8,620' MD (EMPTY) RAN 2.69" CENT. 2' X 1-7/8" STEM, 2.70" CENT, 2.60" MAGNET S/D @ 8,978' MD (1/4 CUP METAL SHAVINGS) ***CONTINUE ON 11/28/23*** 11/28/2023 T/I/O = 320/1600/0+. Temp = 80°. IA FL (pre TIFL). AL online. IA FL @ 5280' (805' above sta # 3 SO). SV = C. WV, SSV, MV = O. IA, OA = OTG. 20:00 11/28/2023 ***CONTINUE FROM 11/27/23*** RAN 1.75" MAGNET TO DEVIATION @ 10,069' SLM (1/8" cup metal shavings) SET 3-1/2" X- DREAM CATCHER @ 2,200' (confirmed w/ check set) ***WELL S/I ON DEPARTURE*** 11/28/2023 T/I/O = 320/1770/0+. Temp = 100*. TIFL (post GLV C/O). AL online @ 1850 psi. IA FL @ 3975' (2110' above sta#3 SO). SV = C. WV, SSV, MV = O. IA & OA = OTG. 14:40. 11/29/2023 T/I/O = 220/1650/10. Temp = 100° TIFL FAILED (post GLV C/O). AL online = 1850 psi. IA FL @ 4230' (1855' above sta # 3, SO). SI WV and stacked out well to 1890/1940/10. Bled IAP to OT to 360 psi in 2 hrs. TP decreased 420 psi. IA FL inflowed 978'. (Failed). Monitored for 1 hr. IAP increased 110 psi, TP increased 100 psi. Final WHPs = 1570/470/20. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00 12/1/2023 T/I/O= 959/2009/4 (HOT OIL TREATMENT) Pumped 5 bbls of 60/40 down IA. SD. Pumped 3 bbls 60/40 and 5 bbls crude down TBG before reaching max psi. TBG frozen. Pumped 287 bbls 190* Crude into IA. ***Job Continued to 12-02-2023*** 12/1/2023 T/I/O = 1150/1990/10. Temp = SI. IA FL (pre-TIFL). ALP = 1990 psi. IA FL @ 6085' (sta#3 SO). Well SI @ IGV. SV = C. WV, SSV, MV = O. IA, OA = OTG. 10:00 12/2/2023 ***Continue Job from 12-01-2023*** Hot Oil Treatment. Pumped 158 bbls (for total of 446 bbls) 190* Crude into IA until TBG obstruction cleared. Pumped 68 bbls 190* Crude into TBG. Pumped 5 bbls 60/40 and 117 bbls Crude into FL for FP. DSO notified upon LRS departure. Valve Positions: SV/WV/SSV = Closed, MV = Open, IA/OA = OTG FWHPs = 762/750/50 Daily Report of Well Operations PBU 02-27A 12/6/2023 ***WELL S/I ON ARRIVAL*** PULL 3-1/2" X DREAM CATCHER @ 2,200' MD (hydrates & paraffin) PUMP 20 BBLS METHANOL RAN 3-1/2" BLB, 2.73" GAUGE RING TO 8,620' MD ***CONTINUE 12/7/23*** 12/7/2023 ***CONTINUE FROM 12/6/23*** ATTEMPT TO SET A CATCHER (tools & wire coming back w/ paraffin) BRUSH & FLUSH TUBING W/ 3 1/2" BRUSH & 2.73" GAUGE RING (hot diesel) SET 3 1/2" WHIDDON CATCHER @ 8,616' SLM (packer area, sat down & couldn't pass gs sheared) PULLED INT-OGLV FROM ST #3 @ 6,085' MD (packing a little torn, check was on seat) SET INT-OGLV (20/64) IN ST #3 @ 6,085' MD ATTEMPT DRAWDOWN TEST ON IA, TUBING TRACKS IA PULLED & SET NEW RK-LGLV IN ST #4 @ 3,800' MD ATTEMPTED DRAWDOWN TEST ON IA W/ SAME RESULTS. PULLED INT-DGLV FROM STA# 1 @ 8524' MD. SET NEW INT-DGLV IN STA# 1 @ 8524' MD. ATTEMPTED DRAWDOWN ON IA; TBG TRACKING. PULLED INT-DGLV FROM STA# 2 @ 7524' MD. ***WSR CONTINUED ON 12-8-23*** 12/7/2023 T/I/O = 1640/1600/Vac. Temp = SI. T & IA FL (SL request). ALP = 1940 psi, SI @ CV. T FL @ 3420' (30 bbls). IA FL @ 4630' (1460' above sta #3 SO, 143 bbls). SL in control of well upon departure. IA & OA = OTG. 15:30 12/7/2023 T/I/O= 2010/2167/6 LRS 76 Assist Slickline (PATCH TUBING/LINER) Pumped 96 bbls 180* Diesel for B&F. FP FL Pumped 3 bbls 60/40 & 115 DSL down FL. Pressured FL to 1500 psi. FWHP = 1000/1765/14 12/8/2023 ***WSR CONTINUED FROM 12-7-23*** SET INT-DGLV IN STA# 2 @ 7524' MD. PERFORMED DRAWDOWN ON IA (PASSED). ATTEMPT TO PULL 3 1/2" WHIDDON FROM 8,616' SLM RAN 2 1/2" PUMP BAILER TO 8,610' SLM, RECOVERED 1/2 GALLON OF SCALE SLURRY RERAN BAILER, EMPTY W/ MARKS ON BOTTOM PULLED EMPTY CATCHER FROM 8,610' SLM ***WELL LEFT S/I ON DEPARTURE*** 12/9/2023 T/I/O = 250/750/20. Temp = 52°. IA FL (post POP). ALP = 1930 psi, SI @ CV. IA FL @ 6085' (sta #3 SO, 160 bbls). SV = C. WV, SSV, MV = O. IA & OA = OTG. 18:00 12/10/2023 T/I/O = 350/780/10. Temp = 70°. IA FL (Post TIFL). ALP = 1800 psi, SI @ CV. IA FL @ 6085' (sta #3 SO). SV = C. WV, SSV, MV = O. IA, OA = OTG. 20:00 Daily Report of Well Operations PBU 02-27A 12/10/2023 T/I/O = 240/760/20. Temp = 72°. TIFL **FAILED** (Post GLV C/O). ALP = 1960 psi, SI @ CV & LV. IA FL @ 6085' (Sta # 3, SO). Well stacked out to 1840/1580/20 in one hr. IA FL inflowed 1085' to 5000'. IAP increased from 1580 psi to 1680 psi in 1 hr. IA FL inflowed 1500' to 3500'. During bleed the tubing pressure increased 160 psi to 2000 psi. OAP was unchanged. Well returned to Ops toPOP. Final WHPs = 2000/1680/20. SV = C. WV, SSV, MV = O. IA, OA = OTG. 12/24/2023 ***WELL FLOWING ON ARRIVAL*** HES 759 R/U ***CONT WSR ON 12/25/2023*** 12/25/2023 T/I/O=2039/1936/30 (PRESSURE TEST INTEGRITY) Assist Slickline. Load TBG w/ 120 bbls crude. *** Job Continued 12-26-23 *** 12/25/2023 ***CONT WSR FROM 12/24/2023*** DRIFT & BRUSH TBG DOWN TO X-NIPPLE @ 8,587' MD W/ 3-1/2" BLB & 2.80" G.RING SET 3-1/2" PX IN X-NIPPLE @ 8,587' MD RAN 4-1/2" CHECKSET TO 4-1/2" PX IN X-NIPPLE @ 8,587' MD SET P-PRONG IN PX IN X-NIPPLE @ 8,587' MD SET 3-1/2" BAITSUB, 2-1/2" SB ON P-PRONG IN PX @ 8,587' MD PULL 1" BTM INT-OGLV FROM STA #3 @ 6,085' MD ***CONT WSR ON 12/26/2023*** 12/26/2023 ***Job Continued from 12-25-23*** (PRESSURE TEST INTERGITY) Pumped 220 bbls crude down tbg for circ out. Pumped 32 bbls to reach test pressure 2500 psi Combo. 15 min loss T-194 / IA-150. 30 min loss T-98 / IA-97 Failed. 2nd combo test pumped .55 bbls to reach 2500 psi. 15 min loss T-104 / IA-98. 30 min loss T-64 / IA-62.Failed. Bled gas cap off IA. Attempted 3rd combo test, pumped 16 bbls crude to reach 2500 psi. 15 min loss T-93 / IA-91. 30 min loss T-43 / IA-43 **PASSED** Bled back to starting pressures, got back 10 bbls. 12/26/2023 T/I/O=846/945/0 Temp=S/I (TFS UNIT 4 Assist SL with D and D hole finder) Pumped 2 bbls of crude down the TBG to assist SL with D and D hole finder. ***********WSR Continued on 12-26-2024************* 12/26/2023 ***CONT WSR FROM 12/25/2023*** SET 1" BTM INT-CIRC VALVE IN STA #3 @ 6,085' MD LRS PERFORM PASSING CMITxIA 2500# (see log for details) PULL 1" BTM INT-CIRC VALVE FROM STA #3 @ 6,085' MD RAN 3-1/2" OK6, PKT BRUSH TO STA #3 @ 6,085' MD SET 1" BTM INT-DMY GLV IN STA #3 @ 6,085' MD PULL 1.5" RK-LGLV FROM STA #4 @ 3,800' MD SET 1.5" RK-DMY GLV IN STA #4 @ 3,800' MD SET 3.5" DND HOLE FIND & TEST TUB (see awgrs for details) PULL 1" BTM INT-DMY GLV FROM STA #1 @ 8,524' MD ***CONT WSR ON 12/27/2023*** 12/27/2023 ***CONT WSR FROM 12/26/2023*** SET/PULL INT-DGLV IN STA #1 @ 8,524' MD (ia tracking) SET EXTENDED PACKING INT-DGLV IN STA #1 @ 8,524' MD (ia tracking) PULLED BAITED SB FROM TOP OF P-PRONG @ 8,587' MD RAN 1.25" LIB TO STA #1 @ 8,524' MD (impression of latch) RAN 3 1/2" D&D HOLE FINDER FROM 8,558' SLM (ia tracking) TO 8,527' SLM (holds 1000psi diff) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU 02-27A 12/27/2023 ***********WSR Continued from 12-26-2023************ (TFS unit 4 assist SL with D and D holefinder) Pumped 13 bbls of crude down TBG to assist SL with D and D holefinder. Well left in SL control Final WHPS 660/738/0 12/28/2023 TFS unit 4 conduct a Freeze Protect on the Flow Line. Pumped 4 bbls of 60/40 followed by 220 bbls of Crude for FP. Pumped 9 bbls of Crude down the FL to pressure FL to 1500 psi per Pad Op. Tags hung 1/1/2024 T/I/O = SSV/1940/0+. Temp = SI. Bleed IAP (WIE request). AL SI @ CV. ALP = 1900 psi. Bled IAP to BT to 200 psi in 40 min (all gas). Monitoed for 60 min. IAP increased 30 psi. psi. Grease crew serviced CV. Final WHPs = SSV/230/0+. SV, WV, SSV = C. MV = O. IA, oA = OTG. 17:00 1/25/2024 *** WELL SHUT IN ON ARRIVAL ***(gas lift integrity) BEGIN R/U HES-769 MOVE TO WEATHER TICKET/ THEN BACK TO OPERATIONS PULL ST# 1 EXTENDED PKG BTM-INT DGLV @ 8,524' MD IN-PROGRESSS - SET ST# 1 BTM-INT DGLV (frudenberg pkg top & btm) @ 8,524' MD ***CONT WSR ON 1/26/24*** 1/25/2024 T/I/O=541/643/0 Temp= S/I (TFS UNIT 4 Assist SL with MIT-T) *********WSR Continued on 1-26-2024************* 1/26/2024 ***CONT WSR FROM 1/25/24***(gas lift integrity) SET ST# 1 BTM-INT DGLV (frudenberg pkg) @ 8,524' MD T/IA TRACK BOTH W/ APPLIED PRESSURE AND NEGATIVE (see log) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** 1/26/2024 **WSR Contiued from 12-25-2024** Assist slickline. MIT T FAILED to 1000 psi.(Integrity) Pressured tubing to 1000 psi with 2 bbls of diesel post slickline setting freundenberg packing. IA tracked. SL still on well. Final WHPS 980/1007/0 2/11/2024 (Assist slickline) TFS U3. Travel to location and standby for slickline. *Job continues to 2-12-24* 2/11/2024 ****WELL S/I ON ARRIVAL**** (Patch tubing/ liner) PULLED 3-1/2" PX PLUG AT 8,587' MD (missing all packing from plug body) RAN 3-1/2" BRUSH & 2.70" G. RING TO PATCH AT 8,978' MD (recovered piece of packing in brush) SET 2.81" x 1.781" NIPPLE REDUCER AT 8,587' MD ATTEMPT TO SET 1.781" XX-PLUG IN NIPPLE REDUCER AT 8,587' MD (pulled nipple reducer out w/ plug) ***CONTINUE ON 2/12/24 WSR*** 2/12/2024 *Job continues from 2-11-24 * T/I/O=150/150/0 (Assist Slickline) TFS U3. MIT- TxIA PASSED at 2427/2368/0 psi. Max Applied 2500 psi, Target Pressure= 2250 psi. Pressure TBG up to 2499 psi and the IA up to 2455 psi with 15 bbls of Crude. In the first 15 minutes the TBG lost 54 psi and the IA 62 psi and in the second 15 minutes the TBG lost 18 psi and the IA lost 25 psi for a total of 72 psi lost on the TBG and 87 psi lost on the IA. Bled the TBG and IA to starting pressures, bled back a total of 11.4 bbls back. Tags hung and well left in control of SL upon departure and DSL notified. Daily Report of Well Operations PBU 02-27A 2/12/2024 ***CONTINUED FROM 2/11/24 WSR*** (Patch tubing/ liner) PERFORM WELL CONTROL DRILL- Review Wells EHS 2024 Topics SET 2.81" x 1.781" NIPPLE REDUCER AT 8,587' MD (confirmed w/ check set) SET 1.781" PLUG IN NIPPLE REDUCER @ 8,587' MD T-BIRD PERFORMED PASSING CMIT T x IA TO 2,500psi RAN 20' x 2.70" WHIPSTOCK TO 8,570' SLM(Patch Drift) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 2/16/2024 *** WELL S/I ON ARRIVAL*** OBJECTIVE : SET NS 3-1/2'' LOWER CROME PATCH 1.81'' ID RIG UP YJ ELINE. PT PCE 300 PSI LOW/ 3000 PSI HIGH RIH CH/ 2-3/4'' CCL /BKR #10/ NS 3-1/2'' CROME PATCH(1.800'' ID) SET LOWER ANCHOR WITH MID ELEMENT AT 8536', CCL TO ME=8.5', CCL STOP=8527.5' TOP AT 8534', BOTTOM AT 8540', OD 2.72" ID 1.81" TAGGED GLM AT 7524 RIH AND GOT HUNG UP AT THE SAME SPOT POOH. ABLE TO WORK THROUGH, BUT IT'S STICKY JOB COMPLETED AND LOWER ANCHOR SET. RDMO YELLOWJACKET ELINE *** WELL S/I ON DEPARTURE*** 2/23/2024 ***WELL S/I ON ARRIVAL*** RUN NS 272 MONO-PAK PACKER,10' x 2 3/8" PUP & SNAP LATCH (2.72" od, 1.81" id, 16.75' oal) @ 8,534' MD (top at 8,517' md) MIT-T W/ LRS TO 1,000 PSI, GOOD TEST (see log for details) PULL 1,78" XX PLUG @ 8,587' MD ***WELL TURNED OVER TO DSO*** 2/23/2024 T/I/O= 20/5/0 Temp= SI. Assist Slickline MIT T PASSED to 982 psi (PATCH TUBING / LINER). Pumped 2.6 bbls to pressure tubing to 1000 psi.. Tbg lost 17 psi in the 1st 15 mins and 1 psi in 2nd 15 mins for a total loss of 18 psi in 30 min test. Bled Tbg to 50 psi and got back ~2 bbls. SL in control of well per LRs departure.Final WHPs 50/60/0 IA,OA=OTG **Tag hung on MV 3/3/2024 ***WELL S/I ON ARRIVAL*** (Patch tubing/ liner) T-BIRD LOADED TBG w/ 101 BBLS DIESEL SET 1.781" RX PLUG IN NIP REDUCER @ 8587' MD T-BIRD PERFORMED MIT-T TO 2500 PSI **PASS** PULLED 1.781' RX PLUG @ 8587' MD ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** 3/3/2024 T/I/O=2391/260/0 Temp= SI Asist slickline MIT T PASSED to 2544 psi (Patch) Loaded well with 104 bbls of diesel. Slickline set pluig. Pumped 3 bbls of of crude to achieve test presure of 2746 psi.Lost 161 psi 1st 15 mins and 41 psi 2nd 15 mins for a total loss of 202 in 30 mins. Bled back 1.6 bbls. Final WHPS=330/318/0 Slickline in control of well upon departure. BOTTOM AT 8540', SET LOWER ANCHOR WITH MID ELEMENT AT RUN NS 272 MONO-PAK PACKER,10' x 2 3/8" PUP & SNAP LATCH (2.72" od, 1.81" id, 16.75' oal) @ 8,534' MD (top at 8,517' md) Daily Report of Well Operations PBU 02-27A 3/7/2024 ***WELL S/I ON ARRIVAL*** (Patch tubing/ liner) POLLARD #60 RIG UP ***CONTINUE ON 3/8/24 WSR*** 3/8/2024 ***CONTINUED FROM 3/7/24 WSR*** (Patch tubing/ liner) HELD WELL CONTROL DRILL WITH CREW HELD MAN DOWN DRILL CREW SET 3-1/2" WHIDDON ON PATCH AT 8,517' MD PULLED INT-DGLV IN STA# 3 AT 3,800' MD & SET INT-OGLV PULLED RK-DGLV IN STA# 4 AT 6,085' MD & SET RK-LGLV ***CONTINUE ON 3/9/24 WSR*** 3/9/2024 ***CONTINUED FROM 3/8/24 WSR*** (Patch tubing/ liner) PULLED 3-1/2" WHIDDON AT 8,517' MD (empty) ***WELL S/I ON DEPARTURE*** 3/19/2024 T/I/O = 370/30/10. Temp = 77°. IA & OA FL (Ops). ALP = 0 psi, SI @ CV. IA FL @ 2120' (3965' above sta # 3 SO). OA FL near surface. SV = C. WV, SSV, MV = O. IA, OA = OTG. 21:00 The milled CIBP fish and both patches are shown correctly on the new WBS, below. -WCB CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:PB Wells Integrity To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); PB Wells Integrity; Bo York; Oliver Sternicki Subject:OPERABLE: Producer 02-27A (PTD #1990930) MIT passed post tubing patch Date:Monday, March 4, 2024 5:51:18 AM Mr. Regg, A patch was set across GLM #1 on 02/23/24 and a subsequent MIT-T passed to 2,544 psi on 03/03/24. With the primary barrier restored, the well is now classified as OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, December 27, 2023 8:41 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Producer 02-27A (PTD #1990930) Tubing Leak Mr., Regg, A tubing tail plug was set at 8587’ MD on 12/25/23 and the well passed a CMIT-TxIA to 2348 psi on 12/26/23, but we were unable to get a passing MIT-T. Follow-up slickline work found a suspected leak in the vicinity of GLM#1 at 8524’ MD. The well is now classified as NOT OPERABLE and will remain shut-in until the tubing barrier is restored. Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 PBU 02-27A PTD 1990930 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, December 8, 2023 2:06 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer 02-27A (PTD #1990930) anomalous IA re-pressurization above MOASP Mr. Regg, Producer 02-27A (PTD #1990930) is currently UNDER EVALUATION for anomalous IA re- pressurization. On 12/07 the well was shut-in to for slickline to perform GLV work and the IAP exceeded MOASP. The reported IA pressure was 2,142 psi. This notification is to satisfy the reporting requirements outlined in CO 492. The well is currently on day 8 of a 28-day clock to resolve the issue. Plan forward: 1. Slickline: Set GL re-design 2. DHD: TIFL 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Friday, December 8, 2023 2:06 PM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Oliver Sternicki; PB Wells Integrity Subject:UNDER EVALUATION: Producer 02-27A (PTD #1990930) anomalous IA re-pressurization above MOASP Mr. Regg, Producer 02‐27A (PTD #1990930) is currently UNDER EVALUATION for anomalous IA re‐pressurizaƟon. On 12/07 the well was shut‐in to for slickline to perform GLV work and the IAP exceeded MOASP. The reported IA pressure was 2,142 psi. This noƟficaƟon is to saƟsfy the reporƟng requirements outlined in CO 492. The well is currently on day 8 of a 28‐ day clock to resolve the issue. Plan forward: 1.Slickline: Set GL re‐design 2.DHD: TIFL 3.Well Integrity: AddiƟonal diagnosƟcs as needed Please respond with any quesƟons. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. PBU 02-27APTD 1990930 · XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. [3 Other, No/Type OVERSIZED · [] · Logs-of various kinds [] Other Complete COMMENTS: · Scanned by: ~ TO RE.SCAN Notes: Dianna Vincent Nathan Lowell Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si STATE OF ALASKA RECEIVED A KA OIL AND GAS CONSERVATION COMMOION OCT REPORT OF SUNDRY WELL OPERATIONS 0 9 2013 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U A'Gcc Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac 0 Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development© Exploratory ❑ 199-093-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21994-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028308 . PBU 02-27A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL/PRUDHOE BAY,PUT RIVER OIL • 11.Present Well Condition Summary: Total Depth measured 11860 feet Plugs measured 9900 feet true vertical 8983.47 feet Junk measured 9878 feet Effective Depth measured 8700 feet Packer measured 8614.62 feet true vertical 7967.35 feet true vertical 7896.18 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 28.5-108.5 28.5-108.5 1490 470 Surface 3338.4 10-3/4"45.5#J-55 29.5-3367.9 29.5 3367.38 3580 2090 Intermediate None None None None None None Production 9263.75 7-5/8"29.7#L-80 28.7-9292.45 28.7-8440.76 6890 4790 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 8986-8996 feet 8996-9010 feet 10022-10042 feet 10042-10052 feet 10090-10115 feet 10140-10730 feet 10860-11170 feet 11299-11745 feet True Vertical depth 8201.83-8209.8 feet 8209.8-8220.93 feet 8962.46-8969.29 feet 8969.29-8972.13 feet 8980.77-8985.87 feet 8989.61-9002.91 feet 9002.36-8996.89 feet 8993.95-8977.32 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#13Cr85 25.52-8695.86 25.52-7963.89 Packers and SSSV(type,measured and true vertical depth) 3-1/2"Baker SABL-3 Packer 8614.62 , 7896.18 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): : r r ; 8986-9010 BANNED �� i ` 4 L C l k Treatment descriptions including volumes used and final pressure: See Attachment 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 561 0 579 0 244 Subsequent to operation: 1834 1509 1374 0 441 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 12 - Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil J • Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCJ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garry.Catron(aBP.Com Printed Name Garry Catron Title PDC PE Signature id C Phone 564-4424 Date 10/9/2013 V L F i l� RBDMS OCT 11 `:c ' ` 0/05//5 ' Form 10-404 Revised 10/2012 Submit Original Only Casing / Tubing Attachment ADL0028308 Casing Length _ Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5#H-40 28.5 - 108.5 28.5 - 108.5 1490 470 LINER 970.37 3-1/2" 8.81# L-80 8682.9 - 9653.3 7953.09 - 8721.58 LINER 675.8 5-1/2" 17# L-80 8997.2 - 9673 8210.76 - 8737.29 7740 6280 LINER 2206.71 3-1/2" 9.2# L-80 9653.3 - 11860 8721.58 - 8983.47 10160 10530 PRODUCTION 9263.75 7-5/8"29.7#L-80 28.7 - 9292.5 28.7 - 8440.76 6890 4790 SURFACE 3338.4 10-3/4"45.5#J-55 29.5 - 3367.9 29.5 - 3367.38 3580 2090 TUBING 8670.34 3-1/2" 9.2# 13Cr85 25.52 - 8695.9 25.52 - 7963.89 10159 10533 • • • • Stimulation or Cement Squeeze Summary Attachment ADL0028308 Treatment descriptions including volumes used and final pressure: Fluids Pumped Downhole: 638 bbls of 25#FlexD X-Link Gel 297 bbls of 25#Linear Gel 196 bbls of 20#Linear Gel 7 bbls of LVT-200 (Mineral Oil) 10 bbls of LVT-200 used for priming pumps to surface tanks Wet Chemicals: Used/Pumped Downhole: 260/247 gals of B882 Gelling Agent 57/57 gals of J604 Crosslink 78/78 gals of U28 mixed at 5% by weight using M002 Caustic Soda (16 Ibs) 67/67 gals of F103 Surfactant 83/83 gals of L64 Clay Stabilizer 42/42 gals of L65 Scale Inhibitor 69/69 gals of J511 Stabilizer Delaying Agent mixed at 10% by weight solution Dry Chemicals: Used/Pumped Downhole: 193/185 lbs of J475 Breaker 30/15 lbs of M275 Microbiocide 28/0 lbs of J134 Enzyme Breaker 56,981 lbs of 16/20 C-Lite Propant Daily Report of Well Operations ADL0028308 q i. ,jA!,YJ T raem4. ***SLB Frac: Job Scope: Fracture Treatment- Put River Sands*** Pump breakdown, scour, data frac, and fracture treatment. After break down decision was made to pump scour stage. NWBF after scour= 363 psi. Datafrac analysis showed frac gradient= 0.61 psi/ft, ISIP = 2440 psi, Pc= 1440 psi, Tc = 8 min, Flulid Eff= 0.5% Pump frac at 25 bpm using YF125FIexD gel system: Pad stage of 150 bbls, 1 PPA Flat stage in 50 bbls, ramp 1 PPA-4 PPA in 50 bbls, ramp 4 PPA-8 PPA in 50 bbls, pump 8 Flat in 50 bbls and 9 ppa flat stage in 100 bbls. Went to 25#XLink Flush, Tripped one pump, second unexplainablly went down attempted to continue pumping screened out and popped PRV • well is not freeze protected. Pulled tree saver with all cups in tacked. Pumped a total of 56,981 lbs of 16/20 Carbolite propant, of which 35,622 lbs was placed behind pipe leaving 21, 359 lbs in 3 1/2" tubing & liner. Propant at 9 PPA in 25# DLink Gel at surface. Note: Master/SSV/Swab all closed to 9/4/2013 prevent sand migration into tree. ***Job Complete*** ***WSR continued from 9-3-13** Heat 5 frac tanks to 98*. Assist with maintaining 2750 psi on IA as directed by Frac crew. Frac crew in controle of well notified DSP upon departure. FWHP= sanded off/980/50 9/4/2013 SV/W/SSV/M/IA/OA= Frac crew CTU #3 1.75" Coil Tubing -Job Scope = Post Frac FCO Stand by for rig up 9/5/2013 <<<Job continued on 9/6/13>>> CTU#3 w/ 1.75" CT. Objective: FCO Post-Frac MIRU. Perform weekly BOP Test. Pass. RIH w/2.25" BJN. Cleaned down to 3500' ctm and chased out. RBIH and started reverse FCO from 3500' ctm. 9/6/2013 «<Job continued on 9/7/13>>> CTU #3 1.75" Coil Tubing -Job Scope = Post Frac FCO «<Job continued from 9/6/13>>> Reverse FCO to 8240'MD. Cracked weld on reel. Risk assessment. Decision to POOH. RDMO to • fix the reel 9/7/2013 «<Job Aborted>>> CTU 8 w/ 1.75" CT, Scope; Post Frac FCO Rig up, Function test BOPs, RIH w/2" BDJSN . Dry tag fill at 8370', cont reverse FCO to 9100'with 80-85% returns.. 9/10/2013 **job continued on WSR 09-11-13** Continued from WSR 09-10-13. CTU 8 w/ 1.75" CT. Scope; post frac FCO Continue reverse cleanout from 9100 to plug at 9870 with returns at 80-90%. After tagging plug circulation was briefly lost, (due to nozzle plugging) pumped down coil and cleared nozzle, swapped back to reverse circ until coil was cleared.. swap to circ long way.. Losses were 60%. Load ball.. POOH reciprocate through all glm's. Freeze protect tubing with 22 bbls 50/50 meth. RD. 9/11/2013 ******JOB COMPLETE****** Daily Report of Well Operations ADL0028308 ***CONT. WSR FROM 9/11/13*** (Post-frac) DRIFT TBG W/2.50" CENT. & S. BAILER TO TD AT 9,741' SLM (recovered full bailer of frac sand)) RAN 3 1/2 WIDDON CATCHER,SET @ 8606'SLM. PULLED 1" INTG-DUMMY FROM STA#3 @ 6078'SLM/6085'MD, PULLED 1.5" RK-DUMMY FROM STA#4@ 3786'SLM/3800'MD. SET 1.5 RK-DOME ( 1500# 16/64) IN STA#4 @3786'SLM/3800'MD, SET 1" INTG-S/O 5/16 IN STA#3@ 6078'SLM/6085'MD. PULLED 3 1/2 WIDDON CATHER @ 8601'SLM,EMPTY,RDMO. 9/12/2013 ***** LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER. ****** • ASRC Test Unit, 1 IL Well 2-27 OL Well 2-28, ***POST FRAC FCO*** RIG UP,PT***Continue to 9/14/2013 WSR 9/15/2013*** ASRC Test Unit, 1 IL Well 2-27 OL Well 2-28, ***POST FRAC FCO***Continue from WSR 9/15/2013 9/14/2013***PT, POP Well ***Continue to WSR 9/16/13**** ASRC Test Unit 1, IL Well 2-27 OL Well 2-28, ***POST FRAC FCO***Continue from WSR 9/16/2013 9/15/2013 ***Flow Well***Continue to WSR 9/17/13**** ASRC Test Unit 1, IL Well 2-27 OL Well 2-28, ***POST FRAC FCO*** Continue from WSR 9/17/2013 9/16/2013 ***Flow Well***Continue to WSR 9/18/13**** ASRC Test Unit 1, IL Well 2-27 OL Well 2-28, ***POST FRAC FCO*** Continue from WSR 9/18/2013 9/17/2013***8 hr Test,Vessel cleanout*** ***job complete*** • • TREE= RC GETI 4 STY NOTES: WELL ANGLE<70°It 10035'. • t"' °= lac 02-27A "'3-12'CHROME TRW- ACRYITOR=---- AXELSON MWL K8.BLS/ 63' - - - BF.REV= 20.CAtsOL1CfOR -110 _ I 2200' H.3-1/7 HES X NP,D=2.813" I KOP= 3931' 1 1 4m AAngle= 95°(4 11538' 91.5#,11940, DBbun AU= 9641' ,D=19.124" (him TVD= 880(Y`SS', GAS LFT MANDRELS 'ST MD TVD DEV TYPE VLV .LATCH.PORT DATE 10-3/4'CSG,45.5#,J-55 BTC,D=9.953' H 3372' 4 3800 3799 7 P.M DOLE RK 16 09/12/13 3 6 36 KBG2 SO NT 20 09/12/13 7-5/8"X 5-1/2"BKR ZXP LW 3990' ►_. _. 2 7524 6993 33 KBG2 DMY NT 0 06/26113 w/TEEM SLV,D= 4. ,.1 Fx 1 8524 7821 34 DMY NT 0 +'•'`*13 [7-5/8"X 5-1/2 FLEX LOG(LNR I-IGR,D=4.800" H 4010' �$ I I "1. I 7' —3-1/2"HES X NP,D=2.813" I 7-5/8"CSG,29.7#,L-80 ABM BTC 4498' 'xi P4 XO TO L-80 BTC * 8620' �5 12,X 3-1/2"BKR S-3 PKR D=2.78• —13-112 HES XN NP,D=2,635" I Minimum ID =2.635" @L) 8687' t 3-1/2" HES XN NIPPLE lir 1.5 7f4c 8683' _—I I-7-5/8"X 5-1/2"ZXP LTR LNR GR,D=4.90" gm'5-1/2'SCAB LNR,17#,L-80 TC1 — . 6 .0238 bpf,D=4.892' { 8701' H 3-1/2'WLFT;,D=2.997 I ELM)TT NOT LOGGED [TOP OF 3-1/2"UsER H 8683' I 3-1/2'TBG,9.2#,13CR-85 VAM TOP, 8700' 8706' -{5 1/2'X 3-1/7 XO,D=2.97' .0087 bpf,D=2.992' TOP OF 5-1/7 LAIR — 9012' .4 L 9017 —7-5/8'X 5-1/2"TM/LIA2 HGR& SETTING SLV,D=? [7-5/8"CSG,29.7#,L-80 BTC,I)=6.875" I 9296' I ■ 1 3-1/2"LNR,8.81#,L-80 STL, 0087 bpf,D=2.997 I- 9653' I— X 5-1/2'MLLOUT 1MsD0W(02-27A1 9673'-9685' 5-1/2"LNR, 17#,L-80 FL4S,.0238 bpf,0=4.982' .H -9673 9878' PER 3-1/2"CBP PALLW&PUS 14.75"WHIPSTOCK(10/16/99) H 9673' (07/19/13)• [5-1/2'BRUCE PLUG(10/15/99) [— 9694' %/ ' ELM -131/7 WED CEP( 1/09) Pli FORATON SUP. RY LOG:SPERRY SIN M D/GR ON 1( 21/99 ANGLE AT TOP PEFF:37°®..<.6 Nate:Refer to Production DB for historical pert data SIZE SW NTERVAL v Opn/Sgz ' SHOT SQZ 2' 6 •»:.-9010 0 08/26/13 2" 6 •.•... -9010 0 08/01/09 2-1/7 4 11299-11745 C 11/24/99 2-1/2" 4 1 -11170 C 11/24/99 = 2-1/7 4 10140-10730 C 11/24/99 PBTT3 —[ 11767' \lip 2-1/2 6 10090-10115 C 06/27/02 2" 6 10022- 10052 C 02/17/06 3-12"L/*,9.2#,L-80 NSCT,_ 7 bpf,0=2,992 H 11 DATE REV BY COMMENTS DATE REV BY COMMENTS F1&U-OE BAY MIT 02/21 N28E INTIAL COMPLETION ' 08/05/13 FIA-VJM) MILLED&RJSIE3)0343(07/19/13) Mil: 02-27A 1 199 N7ES SIDETRACK(02-27A) 08/14/13 SMJM) CHANGED CEP TO FISH PERMT rb:"1"s:*",30 06/28/13 D-14 F O 09/10/13 ATCYJM)REFERF(08/26/13) AR No: 50-029-21994-01 07/01/13 PJC DRLG HO CORRECTION 09/17/13 FACT/JM) GLV 00(09/12/13) SEC 36,T11N,R14E,391'FM_&818'FWL 07/03/13 SAN PJC ANAL ODEAPPROVAL 5/13 ALM'JM)GLV CIO(07/08/13) - Exploration n(Alaska) 4. STATE OF ALASKA t Ak * AWSKA OIL AND GAS CONSERVATION COIISSION REPORT OF SUNDRY WELL OPERATIONS \O 1. Operations Performed: ❑Abandon `10 Repair Well ❑Plug Perforations ❑Perforate ❑Re-Enter Suspended Well Alter Casing , ®Pull Tubing ❑Stimulate-Frac ❑Waiver ❑Other ❑Change Approved Program ❑Operation Shutdown ❑Stimulate-Other ❑Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska)Inc. ❑Exploratory ❑Stratigraphic 199-093 • 3. Address: ®Development ❑Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-21994-01-00 . 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 028308 PBU 02-27A • 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Prudhoe Bay Field/Put River Pool • 11. Present well condition summary: Total depth: measured 11860' feet Plugs:(measured) 9900' feet true vertical 8983' feet Junk:(measured) 9878' feet Effective depth: measured 11767' feet Packer: (measured) 8620' feet true vertical 8978' feet Packer: (true vertical) 7901' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3339' 10-3/4" 33'-3372' 33'-3371' 3580 •" 2090 Intermediate 9263' 7-5/8" 33'-9296' 33'-8443' 6890 4790 Production Liner 661' 5-1/2" 9012'-9673' 8223'-8737' 7740 6280 Scab Liner 4706' 5-1/2" 3990'-8696' 3986'-7964' 7740 6280 Liner 3177' 3-1/2" 8683'- 11860' 7953'-8983' SCANNED NO 1 2 2°13 Perforation Depth: Measured Depth: 8986'- 11745' feet True Vertical Depth: 8202'-8977' feet Tubing(size,grade,measured and true vertical depth): 3-1/2",9.2# 13Cr85 8701' 7968' Packers and SSSV(type,measured and true vertical depth): 5-1/2"x 3-1/2"Baker S-3 Packer 8620' 7901' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: Set 3-1/2"Composite Plug to—8800',Cut&Pull 3-1/2"Tubing at 8668',Mill and Retrieve Packer and Tail Pipe, Run 5-1/2", 17#, L-80 Scab Liner from 3990'-8696',Cement Scab Liner w/100 Bbls,Yield 1.17(480 sx)Class'G', Run 3-1/2",9.2#, 13Cr85 Tubing to 8701', Mill Composite Plug at—8800', Push Composite Plug to 9878' 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1067 2498 299 1800 250 Subsequent to operation: 1094 1816 243 1600 200 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: ❑Exploratory ❑Stratigraphic ®Development ❑Service ®Daily Report of Well Operations 16. Well Status after work: Oil ❑Gas ❑WDSPL ®Well Schematic Diagram ❑GSTOR ❑WINJ ❑WAG ❑GINJ ❑SUSP ❑SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact: Sean McLa • ,564-4387 313-142 Email: Sean.McLaughlin @bp.com Printed am ' Joe L st Title: Drilling Technologist RBDMS AUG 2 0 4 013 Signature. Phone: 564-4091 Date: 'dill/15 Form 10-404 Revised 10/2012 il F /c/1c/ /3 i� 1p! / Submit Original Only • • 02-27A, Well History (Pre Rig Workover) Date Summary 04/05/13 ASSIST ASRC WELL TEST W/FREEZE PROTECT(POST RWO ON 02-15) PUMPED 33 BBLS CRUDE DOWN FL ON PREVIOUS DAY. CONTINUED TO PUMP 38.9 BBLS OF 110*CRUDE DOWN F/L IN ATTEMPT TO CLEAR HYDRATES. UNABLE TO CLEAR HYDRATES. BLED FL DOWN AT MANIFOLD BUILDING AND WELL./PUMPED 7 BBLS NEAT METH SPEAR AND 62 BBLS 50*CRUDE DOWN FL TO FREE UP HYDRATES.AFTER FLOW PATH CLEARED OF HYDRATES, PUMPED AN ADDITIONAL 68 BBLS 110*CRUDE& 10 BBL NEAT METH TAIL DOWN FL @ 2 BPM.ASRC TEST UNIT IN CONTROL OF WELL. FWP=SSV/500/0. 04/11/13 PULL PRONG FROM PX PLUG BODY FROM 8,651'SLM. PULL 3-1/2"PX PLUG BODY FROM 8,656' SLM. DRIFT W/2.77"CENT, 2.50"SAMPLE BAILER-TAG CIBP @ 9,844'SLM. 04/12/13 INITIAL T/I/O =500/500/0. SET 3.5" BAKER COMPOSITE PLUG TOP @ 8798' (MID ELEMENT SET AT 8800'). CUT TBG W/2.5" POWER JET CUTTER @ 8668'. CORRELATED TO TBG TALLY DATED 10/27/1999. FINAL T/I/O=450/450/0. WELL SHUT IN ON DEPARTURE- NOTIFIED DSO OF WELL STATUS. 04/19/13 T/I/O=SSV/500/0+,Temp=SI. PPPOT-T(PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port(1300 psi), bled to 0 psi. Functioned LDS(ET),all moved freely. Pumped through void,good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port(600 psi), bled to 0 psi. Functioned LDS (ET), all moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 04/19/13 T/I/O =460/360NAC.Temp=SI.WHPs T& IA FL(fullbore request). No AL. Integral installed on IA =inspection not current.TBG&IA FL @ surface. SV,WV, SSV=Closed. MV=Open. IA&OA=OTG. NOVP.07:45. 04/20/13 T/I/O=90Nac/0.Temp=SI.Tubing & IA FLs. (Post L&K). No AL.Tubing FL near surface. IA FL @—60' (2 bbls).While checking tubing fluid level the tubing pressure decreased to 70 psi. Hardline rigged up to tubing& IA to tree cap on 02-16. SV,WV=C. SSV, MV=0. IA&OA=OTG. 23:55. 04/20/13 T/I/0=468/468/0 Temp=shut in{L&K TBG& IA}Pumped 5 bbls meth down TBG followed by 305 bbls 9.8 brine and 2 bbls diesel for FP. Pumped 5 bbls meth down IA followed by 441 bbls 9.8 brine and 8.5 bbls diesel for FP. FWHP=519/463/0 IA, OA=OTG SV,WV, SSV=Closed MV=Open. 04/21/13 T/I/O= 110Nac/0.Temp=SI.Tubing& IA FLs. (Post L&K). No AL.Tubing FL @ 420' (4 bbls). IA FL @ —60' (2 bbls). Integral installed on IA=inspection not current. Hardline rigged up on Tubing& IA to tree cap on 02-16.Tubing pressure increased 40 psi,Tubing FL dropped—400'& IA FL unchanged since previous monitor(-4.5 hrs). SV,WV, SSV=C. MV=0. IA&OA=OTG. 04:30. 04/22/13 /I/0 = 120NacNac.Temp=SI.Tubing& IA FLs. (Post L&K). No AL.Tubing FL @ 450' (4 bbls). IA FL @ —60'(-2 bbls). Integral installed on IA=inspection not current. Hardline rigged up from tubing& IA to tree cap on 02-16.Tubing pressure increased 10 psi,Tubing FL dropped—30', OA went on Vac, IAP&IA FL unchanged since 04-21-13 monitor(24 hrs). SV,WV, SSV=C. MV=0. IA&OA=OTG. 04:35. Page 1 of 2 S 02-27A, Well History (Pre Rig Workover) Date Summary 04/23/13 T/I/O= 120NacNac.Temp=SI. Bleed Tubing pressure to 0 psi/FTS. (Post L&K). No AL.Tubing FL @ 450' (4 bbls). Hardline rigged up from Tubing& IA to tree cap on 02-16.WHPs&tubing FL unchanged since previous monitor(-19 hrs). Bled tubing pressure from 120 psi to 0 psi in 20 minutes.Tubing FL rose 200'to 250'during bleed. Monitored for 30 minutes.Tubing pressure increased 4 psi. See log for details.Job complete. Final WHPs=4NacNac. SV,VVV, SSV=C. MV=0. IA&OA=OTG. 01:00. 05/22/13 T/I/O=30NACNAC.Temp=SI. OA FL(Pre MIT-OA).AL spool is dropped.ALP= 1900 psi. OA FL near surface. SV,WV, SSV=C. MV=0. IA, OA=OTG. 2100. 05/23/13 T/I/O=30NACNAC.Temp=SI. MIT-OA to 2000 psi, Bleed WHPs to 0 psi (Pre CTD). MIT-OA= PASS start @ 2000 psi, 1st 15 min, 1941 psi loss of 59 psi,2nd 15 min, 1924 psi loss of 17 psi,total loss of 76 psi. See LOG for details. Bled TP to bleed trailer from 30 psi to 0 psi in 15 min. Final WHPs=ONAC/0. SV, WV, SSV=C. MV=0. IA, OA=OTG.0200. 05/25/13 T/I/O=0/0/0; Conduct PJSM; Start barriers list=SSV&SV verified by independently bleeding TP. LTT passed; R/U lubricator and test against SV to 300 and 3500 psi for 5 min. LTT passed; Open barriers and set 4-1/16"FMC"ISA"BPV#548 through tree for Doyon 14 pre-rig,tag @ 115"; S/I barriers. Page 2 of 2 • • • nca- S � Operation Summary Report Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00.00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/7/2013 00:00 - 01:00 1.00 MOB P PRE MOBILZE RIG. -STAGE RIG AT EDGE OF PAD. -COMPLETE 2-27A PRE-WELL WORK TRANSFER PERMIT WITH DSO. -STAGE WSL OFFICE ON DRILL SITE 2. -PLACE RIG MATS AROUND 2-27A FOR RIG PLACEMENT. 01:00 - 15:30 14.50 MOB P PRE —WAIT WHILE GC-3 SHUTS IN X-PAD FOR GC MAINTENANCE,PREFORM RIG MAINTENANCE. 15:30 - 22:00 6.50 MOB P PRE MOBILZE RIG. -LAY RIG MATS ON X-PAD ACCESS ROAD TO MOVE RIG TO FRONT OF X-PAD. 22:00 - 23:00 1.00 MOB P PRE MOBILZE RIG. -MOVE RIG TO FRONT OF X-PAD TRAVELING ON RIG MATS. 23:00 - 00:00 1.00 MOB P PRE MOBILIZE RIG. -LAY RIG MATS ON X-PAD ACCESS ROAD TO SPINE ROAD, 6/8/2013 00:00 - 01:00 1.00 MOB P PRE MOBILIZE RIG. -LAY RIG MATS ON X-PAD ACCESS ROAD TO u SPINE ROAD. 01:00 - 16:00 15.00 MOB_ P PRE -MOBILIZE RIG. -MOVE RIG FROM X-PAD ENTRANCE ON ' ACCESS ROAD TO SPINE ROAD. -LEAP FROG RIG MATS. 16:00 - 18:30 2.50 MOB P PRE MOBILIZE RIG. -MOVE RIG FROM SPINE ROAD ONTO OXBOW ROAD. 18:30 - 22:30 4.00 MOB P PRE MOBILIZE RIG. -MOVE RIG FROM OXBOW ROAD ONTO WEST DOCK ROAD. 22:30 - 00:00 1.50 MOB P PRE MOBILIZE RIG. -EXIT WEST DOCK ROAD ONTO DRILL SITE 2 ACCESS ROAD. -STAGE RIG,START LAYING MATS OVER PIPE LINE CROSSING AND ACCESS ROAD TO WEST SIDE OF DS2. 6/9/2013 00:00 - 02:00 2.00 MOB P PRE MOBILIZE RIG -PJSM,MOVE RIG FROM DS 2 ENTRANCE AROUND RESERVE PIT ONTO CENTER PAD AND STAGE FOR PULLING OVER 2-27A. *BOPE TEST 24 HOUR NOTICE SENT TO AOGCC AT 12:53 AM FOR TESTING AT 2 AM ON 6/10/2013 02:00 - 03:00 1.00 MOB P PRE MOBILIZE RIG. -CHECK IA,OA AND WELLHEAD PRESSURE, ALL AT 0 PSI. -HOLD PJSM WITH CREW FOR MOVING OVER WELL. -FUNCTION MOVE SYSTEM ESD. -MOVE OVER WELL 2-27. `PAD OPERATOR WAIVED WITNESS FOR MOVE OVER WELL. Printed 7/8/2013 10:06:11AM • orth America-ALASKA BPS'' � � � _� � Operation Summary Report' Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 06:00 3.00 RIGU P PRE SECURE RIG MIRU ON 2-27A -SKID RIG FLOOR INTO DRILLING POSITION. -HOOK UP RIG FLOOR CONNECTIONS. -SLIDE CONVEYOR FOR ROCK WASHER INTO POSITION. -SPOT ROCKWASHER. -HARD LINE CREW RIGGING UP FLOW BACK -TANK AND HARD LINE. -TEST HARD LINES FROM TANK TO CHOKE 'MANIFOLD SKID. PRESSURE TEST TO 250 PSI.LOW/3500 PSI. HIGH. 06:00 - 07:00 I 1.00 RIGU P PRE RIG ACCEPTED AT 06:00,6-9-2013. -TAKE ON 9.8 BRINE TO PITS. 'UPRIGHT TANK SPOTTED,TAKE ON 300 BBLS OF 9.8 CONTINGENCY FLUID. 07:00 - 09:00 2.00 RIGU P PRE RIG UP TO DISPLACE FREEZE PROTECT DIESEL W/9.8 BRINE TO FLOW BACK TANK. 09:00 - 10:00 1.00 RIGU P PRE H2S RIG EVACUATION DRILL,RESPONSE TIME=4:30 MINS. -TEST ESD SYSTEM,TEST SUCCESSFUL ,-CONDUCT AAR. 10:00 - 11:00 1.00 RIGU P PRE RIG UP TO DISPLACE FREEZE PROTECT _.DIESEL W/9.8 BRINE TO FLOW BACK TANK. *BOP TEST WITNESS WAS WAIVED BY AOGCC REP.JEFF JONES AT 10:02 AM, 6-9-2013. 11:00 - 13:30 2.50 WHSUR_ P DECOMP PRESSURE TEST HARD LINES TO FLOW BACK TANK. -TEST MUD LINES AND CELLAR HOSE FROM TREE TO CHOKE MANIFOLD. PRESSURE TEST TO 250 PSI.LOW/3500 PSI. HIGH FOR 5 MINS. -TEST HARD LINES FROM TANK TO CHOKE MANIFOLD SKID. PRESSURE TEST TO 250 PSI.LOW/3500 PSI. HIGH FOR 5 MINS. -BLOW DOWN LINES. 13:30 - 17:00 3.50 WHSUR P DECOMP PULL BACK PRESSURE VALVE -MOBILIZE LUBRICATOR TO RIG FLOOR. -PJSM,PRESSURE TEST LUBRICATOR TO 250 PSI.LOW/3500 PSI.HIGH FOR 5 CHARTED MINS EACH. -PULL ISA BPV. -RIG DOWN LUBRICATOR. 17:00 - 18:00 1.00 WHSUR P DECOMP CIRCULATE OUT DIESEL FREEZE PROTECT W/9.8 BRINE. -PJSM,PUMP 9.8 PPG BRINE DOWN IA WTH 2.5 BPM AT 100 PSI., TOOK 15 BBLS TO FILL,PUMPED ADDITION 5 BBLS OUT. -PUMP 9.8 PPG BRINE DOWN TUBING WIITH 2.6 BPM AT 200 PSI. TOOK 10 BBLS TO FILL,PUMPED ADDITIONAL 20 BBLS. -PUMPED A TOTAL OF 50 BBLS. 18:00 - 18:30 0.50 WHSUR P DECOMP FLOW CHECK FOR 10 MINS,WELL ON A VACUUM. -SHUT IN MASTER VALVE ON TREE. -BLOW DOWN LINES. Printed 7/8/2013 10:06:11AM • % .• 1 North America-ALASKA-BP f Page or f , ' Operation Summary Report' Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 22:00 3.50 WHSUR P DECOMP INSTALL NEW ISA BACK PRESSURE VALVE ON TESTED LUBRICATOR. -PJSM,PRESSURE TEST LUBRICATOR TO 250 PSI LOW/3500 PSI.HIGH FOR 5 CHARTED MINS.EACH. -ATTEMPT TO TEST WITH SSV CLOSED,TEST LEAKED OFF WITH NO EXTERIOR LEAKS —OBSERVED. -OPEN SSV AND TEST AGAINST MASTER 'VALVE,TEST SUCCESSFUL. -INSTALL NEW ISA BPV. 22:00 - 23:00 1.00 WHSUR P DECOMP 'PRESSURE TEST BACK PRESSURE VALVE. -PJSM,ROLLING TEST FROM BELOW TO 500 PSI FOR 10 MINS. -PUMP DOWN IA,MONITOR FOR FLOW BACK 1 FROM TREE. TOOK 17 BBLS TO FILL IA,8 BBLS TO PRESSURE UP TO 500 PSI. -CIRCULATE 3.2 BPM WITH 710 PSI. -PUMPED AWAY 40 BBLS TO MAINTAIN 500 PSI FOR 10 MINS.,OA PRESSURE CAME UP TO 1000 PSI. -TEST COMPLETED AND OA BLED OFF TO 0 PSI. 23:00 - 00:00 1.00 WHSUR P DECOMP H2S RIG EVACUATION DRILL,RESPONSE TIME=3:08 CONDUCT AAR. 6/10/2013 00:00 - 02:00 2.00 WHSUR P DECOMP NIPPLE DOWN TREE. -PJSM, ND TREE AND ADAPTER FLANGE. -REMOVE ALL BUT 4 NUTS FROM ADAPTER FLANGE TO TREE. -SLOWLY BREAK SEAL BETWEEN TREE AND ADAPTER FLANGE. -VERIFY NO FLUID COMING PAST BPV. REMOVE ALL BUT 4 NUTS FROM ADAPTER FLANGE TO WELLHEAD. -SLOWLY BREAK SEAL BETWEEN ADAPTER FLANGE AND WELLHEAD AND VERIFY TUBING HANGER PACK OFF HOLDING. -REMOVE TREE AND ADAPTER FLANGE FROM WELL HEAD. *CONFIRM TUBING AND IA PRESSURE IN ZERO. **GRAVITY FEEDING IAAT 26 BPH. 02:00 - 02:30 0.50 WHSUR P DECOMP VERIFY TUBING HANGER THREADS. -TUBING HANGER THREADS 9"LH ACME X-09. -INSTALL ISA BLANKING PLUG AND XO TO 4.5" IF FOR TESTING AND GET MEASUREMENTS TO ENSURE CLEARANCE FOR TEST JOINTS TO 3.5"X6"VBRS.ASSEMBLY HEIGHT 24.25" ABOVE WELLHEAD FLANGE. -REMOVE XO. **GRAVITY FEEDING IAAT 26 BPH. 02:30 - 07:00 4.50 WHSUR P DECOMP NIPPLE UP BOPS -TOP TO BOTTOM CONFIGURATION. *ANNULAR PREVENTER. *3.5"X6"VBR. *BLIND/SHEAR. *MUD CROSS WITH CHOKE AND KILL OUTLETS. *2 7/8"X5"VBR. **GRAVITY FEEDING IAAT 26 BPH. Printed 7/8/2013 10:06:11AM • } North America-ALASKA BP 'w'''°a'0i' �� � Operation Summary Report Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:00 - 08:00 1.00 BOPSUR P DECOMP RIG UP BOP TEST EQUIPMENT. **GRAVITY FEEDING IA AT 26 BPH. 08:00 - 09:00 1.00 BOPSUR P DECOMP BOP DRILL. -TEST FILL ON CHOKE MANIFOLD,TOOK 6 BBLS TO FILL. **GRAVITY FEEDING IA AT 26 BPH. 09:00 - 18:00 9.00 BOPSUR P DECOMP _BOPE TEST. -PJSM,TEST BOPE TO 250 PSI.LOW/3500 PSI HIGH FOR 5 MINS EACH. *ANNULAR PREVENTER TESTED WITH 2 7/8" TEST JOINT *3:5"X6"VBR TESTED WITH 3-1/2"AND 5-1/2" TEST JOINTS. *2 7/8"X5"VBR TESTED WITH 2 7/8"AND 4" TEST JOINTS. -ALL TEST CHARTED,SEE ATTACHED BOP TEST CHARTS. - -ACCUMULATOR BRAWDOWN TEST. *TEST WITNESS WAIVED BY AOGCC REP. JEFF JONES. **ALL TEST PERFORMED TO AOGCC,DDI AND BPXA SPECS. ***GRAVITY FEEDING IAAT26 BPH. 18:00 - 20:00 2.00.-._. BOPSUR R DECOMP RIG DOWN BOP TEST EQUIPMENT. -PJSM,BLOW DOWN CHOKE AND KILL LINE. -VOID BOP STACK OF FLUIDS. -MOBILIZE DUTCH RISER AND LUBRICATOR TO RIG FLOOR. **GRAVITY FEEDING IA AT 26 BPH. 20:00 - 22:00 2.00 MOB P DECOMP RIG UP DUTCH RISER. -PJSM,R/U DUTCH RISER ON BOP STACK. -RUN IN LOCK DOWN SCREWS FOR DUTCH RISER. **GRAVITY FEEDING IA AT 26 BPH. 22:00 - 23:00 1.00 PULL P DECOMP PRESSURE TEST LUBRICATOR. -PJSM,R/U AND TEST LUBRICATOR AND DUTCH RISER. PT 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MINS EACH-FAILED TEST. **GRAVITY FEEDING IAAT 26 BPH. 23:00 - 23:30 0.50 PULL N SFAL DECOMP REPLACE O RING ON LUBRICATOR AND DUTCH RISER -CHANGED OUT LUBRICATOR SEAL -CHANGED OUT SEAL ON DUTCH RISER ACME THREAD CROSS OVER. -RETEST LUBRICATOR 250/3500 PSI FOR 5 CHARTED MINUTES EACH.TEST PASS. **GRAVITY FEEDING IAAT 26 BPH. 23:30 - 00:00 0.50 PULL P DECOMP REMOVE 9"ACME BLANKING PLUG FROM TUBING HANGER. -PULLED OUT LUBRICATOR WITH DUTCH RISER ATTACHED. -RIH WITH BLANKING PLUG CROSS OVER ON DRILL PIPE,PULL BLANKING PLUG. **GRAVITY FEEDING IA AT 26 BPH. Printed 7/8/2013 10•06:11AM North America-ALASKA BP/ 4v, Operaua ort tion S mm e Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12.00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 6/11/2013 ,00:00 - 01:30 1.50 WHSUR P DECOMP PULL ISA BACK PRESSURE VALVE. j -FLOW CHECK WELL FOR 10 MINS.,WELL ON VACUUM. -RIG UP AND PULL BPV. *BLED OF OA PRESSURE FROM 600 PSI.TO 0 PSI.TO FLOW BACK TANK. **FILL WELL ACROSS TOP AT 26 BPH. ***BARRIER CHANGE-COMPOSITE PLUG, KWF AND TESTED BOP 01:30 - 02:30 1.00 WHSUR P DECOMP RIG DOWN LUBRICATOR AND DUTCH RISER. -MOBILIZE OFF RIG FLOOR. -INSTALL BALES ON TOP DRIVE. **FILL WELL ACROSS TOP AT 26 BPH 02:30 - 03:30 1.00 PULL P DECOMP PULL 11"TUBING HANGER. -M/U JOINT OF DRILL PIPE TO 9"LH ACME CROSS OVER. -RIH AND SCREW INTO TUBING HANGER. -BACK OUT LOCK DOWN SCREWS. -PULL 125K ON LANDING JOINT/TUBING HANGER TO BREAK FREE. -PULL TUBING HANGER TO RIG FLOOR WITH 120K UP WEIGHT. *BARRIERS:COMPOSITE PLUG,KWF, "TESTED BOPE. 03:30 - 05:30 2.00 PULL P DECOMP CIRCULATE BOTTOMS UP. -CLOSE ANNULAR AND LINE UP TO TAKE RETURNS THROUGH CHOKE AND MGS. -PUMP 9.8 BRINE AT 6 BPM WITH 470 PSI. -SHUT DOWN PUMPS AND MONITOR WELL FOR 10 MINUTES AND CONFIRM DEAD-WELL STATIC. *SIMOPS-PJSM,RIG UP DDI CASING CREW AND EQUIPMENT. **LOST 8 BBLS DURING BOTTOMS UP CIRCULATION. 05:30 - 12:00 6.50 PULL P DECOMP PULL AND LAY DOWN 3.5"TUBING FROM 8,638'TO 3,132'. -DISCONNECT TOP DRIVE FROM LANDING JOINT. -LAY DOWN LANDING JOINT AND HANGER. -BLOW DOWN TOP DRIVE. -POOH LAYING DOWN 3.5"TUBING AND JEWELRY. -AT 4,225"FLUID BECAME OUT OF BALANCE, CIRC 7 BPM,287 GPM WITH 400 PSI., PUMPED 150 BBLS. 'FILLING HOLE ACROSS THE TOP REPLACING LOSSES AND TUBING DISPLACEMENT. **TOTAL LOSSES AT CREW CHANGE:190 BBLS. 12:00 - 12:30 0.50 PULL P DECOMP SERVICE RIG. -LUBRICATE AND INSPECT DRAW WORKS AND BRAKES. 12:30 - 16:00 3.50 PULL P DECOMP PULL AND LAY DOWN 3-1/2"9.3#L-80 EUE 8RD TUBING F/3,132'T/SURFACE. -AT 1,200'FLUID BECAME OUT OF BALANCE, CIRC 6.5 BPM,287 GPM WITH 310 PSI., PUMPED 72 BBLS. -CUT LENGTH=7.55',W/3.875 OD FLARE. -TOTAL JOINTS OUT=274,3 GLM'S,1 X-NIPPLE. Printed 7/8/2013 10:06:11AM • gi North America-ALASKA BP Operation Summary Report Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4 OOX8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 18:00 2.00 FISH P DECOMP MOBILIZE 7-5/8"X 4-1/2"PACKER MILLING BHA TO FLOOR. -PJSM,BEAVER SLIDE OPERATIONS. -CLEAN CASING TOOLS AND REMOVE FROM FLOOR. -MOBILIZE PACKER MILL BHA COMPONENTS TO RIG FLOOR. -INSTALL WEAR BUSHING.(7.0625"ID, LENGTH=12") t*SPILL DRILL. 18:00 - 20:00 2.00 FISH P DECOMP j MAKE UP PACKER MILLING BHA. '-PJSM,MAKE UP MILLING ASSEMBLY AND RIH T/315'. 20:00 - 00:00 4.00 FISH P DECOMP RIH WITH 6-3/4"PACKER MILLING ASSEMBLY FROM 315 TO 4,208'. 1-PJSM,RIH ON ELEVATORS PICKING UP4" DRILL PIPE. -PUW 117K,SOW 80K. *TOTAL LOSSES AT CREW CHANGE:103 BBLS. *293 BBLS LOST LAST 24 HOURS. 1*CURRENT LOSS RATE IS 10 BBL/HR. **KICK WHILE TRIPPING DRILL. 6/12/2013 00:00 - 00:30 0.50--- FISH- P DECOMP SERVICE AND INSPECT ALL DRILL PIPE HANDLING EQUIPMENT. -LUBRICATE IRON ROUGHNECK. 00:30 - 04:30 4.00 FISH P DECOMP RIH VNTH 6-3/4"PACKER MILLING ASSEMBLY FROM 4,208'TO 8,641'. -RIH ON ELEVATORS PICKING UP 4"DRILL PIPE. 04:30 - 12:00 7.50 FISH P DECOMP MILL 7-5/8"X 4-1/2"BAKER S-3 PACKER WITH 6-3/4"PACKER MILL FROM 8,661'TO 8,663. -MAKE UP TOP DRIVE,OBTAIN SPR'S AND MILLING PARAMETERS. -PUMPS OFF PUW 190K. -PUMPS ON AT 5 BPM WITH 650 PSI.,PUW 188K,SOW 162K,ROT 172K AT 40 RPM'S WITH 2 TO 4K TORQUE OFF BOTTOM. -STOP ROTATION AND TAG TOP OF 3-1/2" !TUBING STUB AT 8,661'. -PICK UP TO 8,656'AND ROTATE AT 60 RPM'S WITH 2 TO 4K TORQUE OFF. -CLOSE MANUAL CHOKE AND KILL VALVES TO MINIMIZE METAL IN LINES. -MILL ON TUBING STUB FROM 8,661'TO 8,663' I WITH 2 TO 6K TORQUE ON AND PUMPS AT 5 BPM WITH 620 PSI. -PUMPED TWO HI-VIS SWEEPS WITH MINIMAL METAL RETURNS. *TOTAL LOSSES AT CREW CHANGE:90 BBLS. Printed 7/8/2013 10:06:11AM ,� �� North America-ALASKA BP�� $ f Operation Summary Report>r. Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-0OX8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 19:30 7.50 FISH P DECOMP MILL 7-5/8"X 4-1/2"BAKER S-3 PACKER WITH 6-3/4"PACKER MILL FROM 8,663'TO 8,667'. -PUMPS ON AT 5 BPM WITH 640 PSI,PUW 190K,SOW 160K,ROT 174K AT 100 RPM WITH 3 TO 7K TORQUE ON BOTTOM.WOB 7 TO 10K. -PUMPED TWO MORE HI-VIS SWEEPS WITH NO MORE METAL OBSERVED ON MAGNETS. -WHEN MILLING ASSEMBLY REACHED 8,667' OBSERVED PRESSURE,TORQUE AND WOB DECREASE. I-OA OPEN TO FLOW BACK TANK @ 13:55_ 19:30 - 21:00 1.50 FISH P ` DECOMP CIRCULATE THROUGH MUD GAS SEPARATOR. '-PJSM,PICK UP STRING T/8,640'SHUT IN ANNULAR PREVENTER AND FILL U-TUBE AND MGS VESSEL. -LINE UP CHOKE MANIFOLD TO TAKE RETURNS THROUGH MGS.AND CIRC SURFACE TO SURFACE MUD VOLUME. -CIRCULATE SURFACE TO SURFACE AT 6 BPM WITH 870 PSI. -AT BOTTOMS UP OBSERVED PRESSURE -INCREASE ON CASING FROM 20 PSI.TO 70 'PSI.WITH NO PSI.INCREASE ON U-TUBE GAUGE AFTER 15 MINUTES PRESSURE ON CASING RETURNED TO 20 PSI. -OBSERVED PACKER GAS VENTING FROM MGS STACK. -PUMPED A TOTAL OF 400 BBLS. *WELL KILL DRILL. 21:00 - 21:30 0.50 FISH P DECOMP WASH DOWN AND TAG PACKER. -FLOW CHECK WELL FOR 10 MINS.,WELL ON A VACUUM. -OPEN ANNULAR PREVENTER. -OBTAIN SPR'S AND PARAMETERS. -PUMPS ON AT 5 BPM WITH 780 PSI.AT 80 RPM WITH 4K TORQUE.-WASH DOWN TO PACKER AND PUT 5K WOB AT 8667'. -WASHED DOWN TWICE TO MAKE SURE NO DEBRIS INSIDE PACKER. -NO PROBLEMS OR DEBRI OBSERVED WHEN STINGING INTO PACKER WITH THE 2' 2-7/8"ROUND NOSE MILL. -PUMPS OFF,POOH F/8,667 T/8,577' STANDING BACK 4"DRILL PIPE. -BLOW DOWN TOP DRIVE,CHOKE AND KILL LINE. 21:30 - 00:00 2.50 FISH P DECOMP ,POOH WITH 6-3/4"MILLING ASSEMBLY. -PJSM,POOH F/8,577' T/3,449'STANDING BACK 4"DRILL PIPE. -PUW=111K,SOW=111KAT 3,449'. -OA REMAINS OPEN TO FLOW BACK TANK SINCE 13:55 WITH NO FLUIDS OBSERVED IN PREPARATION FOR PACK-OFF CHANGE OUT. *TOTAL LOSSES AT CREW CHANGE:39 BBLS. *139 BBLS LOST LAST 24 HOURS. *CURRENT LOSS RATE IS 2 BBL/HR. **BARRIERS ARE COMPOSITE PLUG AT 8,800', FULL HOLE OF 9.8 PPG KWF,TESTED BOPE, DOUBLE CASING VALVES. Printed 7/8/2013 10:06:11AM • , t4,14.fir North America-ALASKA BP fir, %; % //:/./ r Operation Summary Report Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date.6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/13/2013 00:00 - 01:00 1.00 FISH P DECOMP POOH WITH 6-3/4"PACKER MILLING ASSEMBLY. -STAND BACK 4"DRILL PIPE F/3,449'T/410'. -FLOW CHECK WELL BEFORE PULLING NONSHEARABLES THROUGH BOPE STACK -FLUID LEVEL DROPPING. 01:00 - 02:30 1.50 FISH P DECOMP POOH WITH 6-3/4"PACKER MILLING ASSEMBLY BHA. STAND BACK LAST STAND OF 4"DRILL PIPE. -STAND BACK 3 STANDS OF 4-3/4"DRILL COLLARS. -BREAK OFF 2-7/8"PILOT ROUND NOSE MILL, 6-3/4"PACKER MILL,BOOT BASKETS AND BIT SUB FROM BUMPER.SUB. -CLEAN OUT 3 4-3/4"BOOT BASKETS. -RETRIEVED 2 GALLONS FROM BASKETS AND 1/2 GALLON FROM DITCH MAGNETS IN PITS. -TOTAL OF 40 LBS.OF METAL SHAVINGS , RECOVERED. -REMOVE MILLING COMPONENTS FROM FLOOR AND BRING IN SPEAR AND INTENSIFIER. 02:30 - 03:00 0.50 FISH P DECOMP" SERVICE IRON ROUGHNECK -GREASE AND INSPECT ST-80,SLIPS AND , ELEVATORS. 03:00 - 03:30 0.50 FISH P DECOMP ASSEMBLE AND RIH WITH 2-13/16"SPEAR ASSEMBLY FOR RETRIEVING PACKER. -PICK UP AND MAKE UP SPEAR ON JARS AND BUMPER SUB AND PLACE IN HOLE. -SET PUMP OUT SUB IN JARS. -RIH WITH 4-3/4"DRILL COLLARS FROM DERRICK T/300'. -P/U AND M/U INTENSIFIER AND RIH T/310'. 03:30 - 07:30 4.00 FISH P DECOMP RIH WITH 2-13/16"SPEAR ASSEMBLY FOR RETRIEVING PACKER. -RIH WITH 4"DRILL PIPE F/310'T/6,300'. *WELL IS CURRENTLY STATIC WITH PROPER DISPLACEMENT. **BARRIERS ARE COMPOSITE PLUG AT 8,800', FULL HOLE OF 9.8 PPG KWF,TESTED BOPE, DOUBLE C ASING VALVES. 07:30 - 09:00 1.50 FISH P DECOMP SLIP AND CUT DRILLING LINE. -FLOW CHECK WELL FOR 10 MINS.,WELL ON SLIGHT VACUUM. -PJSM,SLIP AND CUT 59.5 FT.OF DRILLING LINE. 09:00 - 10:00 1.00 FISH P DECOMP ENGAGE PACKER AND TAIL PIPE ASSEMBLY WITH 2-13/16"SPEAR IN TAIL PIPE. -MAKE UP TOP DRIVE AND RUN IN HOLE F/ 8,600',TO 8,609'. -OBTAIN SPR'S AND FISHING PARAMETERS. -PUW 192K,SOW 162K.PUMPS ON AT 3 BPM W/690 PSI. -TAGGED FISH AT 8,667'. -SLACK BACK OFF AND PUT 15K DOWN ON FISH,PICKED UP AND NOTICED WEIGHT INCREASE 10 TO 15K WHEN PACKER CROSSED CASING COLLARS AT 8,646'AND 8,602'. Printed 7/8/2013 10:06:11AM • • "" OFF North America-ALASKA BP /'Operation Summary Report f.;, F/ �l, r; Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27©60.65usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1 _ 10:00 - 10:30 0.50 FISH P DECOMP CIRCULATE SURFACE TO SURFACE TO MITIGATE ANY GAS. -PICK STRING UP TO 8,605',CLOSED ANNULAR PREVENTER. -CIRCULATE THROUGH THE MUD GAS SEPARATOR AT 5 BPM WITH 1970 PSI. -FLOW CHECK WELL,VERIFY NO PRESSURE. -OPEN ANNULAR PREVENTER. *TOTAL OF 400 BBLS.CIRCULATED. 10:30 - 11:00 0.50 FISH P DECOMP FLOW CHECK WELL FOR 10 MINS.,WELL ON SLIGHT VACUUM. -RUN IN HOLE F/8,605'TAG BOTTOM AT 8,669' WITH 15K ON FISH. 11:00 - 12:00 1.00 FISH P DECOMP PULL OUT OF HOLE WITH 2-13/16"SPEAR ASSEMBLY. -OBSERVED 50 TO 60K OVERPULLAT 8,646' AND 8,602'. - -STAND BACK ONE STAND,BLOW DOWN TOP DRIVE AND CHOKE. -POOH F/8,609'T/8,482'STANDING BACK 4" DRILL PIPE. -PM 190K,SOW 160K. -OA REMAINS OPEN TO FLOW BACK TANK SINCE 13:55 ON 06/12/2013 WITH NO FLUIDS OBSERVED IN PREPARATION FOR PACK-OFF CHANGE OUT. *TOTAL LOSSES AT CREW CHANGE:15 BBLS. 12:00 - 12:30 0.50 FISH P DECOMP SERVICE RIG. -LUBRICATE AND INSPECT DRAW WORKS. -INSPECT BRAKES. 12:30 - 13:00 0.50 FISH P DECOMP PULL OUT OF HOLE WITH 2-13/16"SPEAR ASSEMBLY. -STAND BACK 4"DRILL PIPE F/8,482'T/6,867'. _ 13:00 - 14:30 1.50 FISH N HMAN DECOMP SAFETY STAND DOWN,INJURY INVESTIGATION. -STOPPED RIG OPERATIONS DUE TO HAND INJURY,TRACTION INCIDENT REPORT: 2013-1R-4446999. -OBTAINED WITNESS STATEMENTS AND PICTURES OF RE-ENACTMENT. -AAR WITH WHOLE CREW IN DOGHOUSE. -MONITOR WELL BORE FLUIDS THROUGH TRIP TANK,CIRCULATE ACROSS THE TOP. 14:30 - 17:30 3.00 FISH P DECOMP PULL OUT OF HOLE WITH 2-13/16"SPEAR ASSEMBLY. -STAND BACK 4'DRILL PIPE F/6,867'T/405'. 17:30 - 19:00 1.50 FISH P DECOMP HANDLE 2-13/16"SPEAR ASSY BHA. -FLOW CHECK WELL FOR 10 MINS.FOR NONSHEARABLES ACROSS STACK,WELL ON SLIGHT VACUUM. -UD INTENSIFIER,RACK BACK 3 STANDS OF 4-3/4"DRILL COLLARS. -PULL BHA TO SURFACE,PACKER WAS NOT ON SPEAR. *DISCUSSED PLAN FORWARD WITH ODE AND WITH BOT SUGGESTION OF RUNNING SPEAR DRESSED WITH GRAPPLE TO CATCH PACKER INSTEAD OF TAIL PIPE. Printed 7/8/2013 10:06:11AM • S oify< 4` North America-ALASKA-BP , a�10 o Operation Summary Report Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 1X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 19:30 0.50 FISH P DECOMP PICK UP 3-1/4"SPEAR DRESSED WITH 3.885" GRAPPLE. -CLEAR AND CLEAN RIG FLOOR. -MOBILIZE 3-1/4"SPEAR TO RIG FLOOR !THROUGH BEAVER SLIDE. 19:30 - 20:30 1.00 FISH P DECOMP j MAKE UP 3-1/4"SPEAR ASSEMBLY BHA FOR CATCHING PACKER BODY. -CHANGE OUT 2-13/16"SPEAR WITH A 3-1/4" SPEAR. -RIH TO 311'WITH 4-3/4"DRILL COLLARS FROM DERRICK AND INTENSIFIER FROM PIPE SKATE. 20:30 - 00:00 3.50 FISH P DECOMP RIH WITH 3-1/4"SPEAR ASSEMBLY BHA FOR CATCHING PACKER BODY. -PJSM,RUN IN HOLE F/311'T/3,255'ON 4" DRILL PIPE. -PUW 102K,SOW 104K. -OA REMAINS OPEN TO FLOW BACK TANK SINCE 13:55 ON 06/12/2013 WITH NO FLUIDS OBSERVED IN PREPARATION FOR PACK-OFF CHANGE OUT. *TOTAL LOSSES AT CREW CHANGE:12 BBLS. *27 BBLS LOST LAST 24 HOURS. *CURRENT LOSS RATE IS 1.125 BBL/HR. **BARRIERS ARE COMPOSITE PLUG AT 8,800', FULL HOLE OF 9.8 PPG KWF,TESTED BOPE, DOUBLE CASING VALVES. 6/14/2013 00:00 - 00:30 0.50 FISH _ P , DECOMP RIH WITH 3-1/4"SPEAR ASSEMBLY FOR 'CATCHING PACKER BODY. -RIH WITH 4"DRILL PIPE FROM DERRICK F/3,255'T/8,383'. 00:30 - 01:00 0.50 FISH P DECOMP ENGAGE FISH. -OBTAIN PARAMETERS:PUW 190K,SOW 160K,WITH PUMPS ON AT 3 BPM WITH 370 I PSI. -TAG FISH AT 8,667'OBSERVE PRESSURE INCREASE TO 450 PSI.SET 10K ON FISH AND PICKED UP 5 FT. -RUN BACK IN HOLE AND TAGGED AGAIN WITH 15K AT 8,669',PRESSURE INCREASED TO 1200 PSI. -PICK UP 5 FT.OBSERVED PSI.DECREASE BACK TO 370 PSI. AND TAGGED ONE MORE TIME WITH 15K ON FISH,NO GAIN IN DEPTH. -SHUT DOWN PUMPS AND BLEED STAND PIPE. 01:00 - 05:30 1 4.50 FISH P DECOMP PULL OUT OF HOLE WITH 3-1/4"SPEAR ASSEMBLY FOR CATCHING PACKER BODY. -PJSM,FLOW CHECK WELL FOR 10 MINS., WELL STATIC. -POOH STANDING BACK 4"DRILL PIPE F/ 8,669'T/8,605'. I-BLOW DOWN TOP DRIVE. -POOH STANDING BACK 4"DRILL PIPE F/ 8,669'T/406'. *WORK PACKER THROUGH COLLARS F/8,669' T/8,380'WITH 50K TO 60K OVERPULL'S. *AFTER OVERPULLAT 8,380'DID NOT OBSERVE ANY MORE OVERPULL'S. *LOSSES ARE CURRENTLY 6 BBLS.OVER J. DISPLACEMENT. Printed 7/8/2013 10:06:11AM • g '-„�rr ^/� r l F� r � ,r.f / f,/,.,/ ,% Operation Summary Reports/ , , Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT 1 NPT Depth ! Phase !I Description of Operations _ r (usft) DECOMP PULL OUT OF HOLE WITH 3-1/4”SPEAR 05:30 08:30 3.00 P 0 FISH II ASSEMBLY BHA FOR CATCHING PACKER BODY. -PJSM,FLOW CHECK WELL FOR 10 MINUTES. I BEFORE PULLING NON SHEARABLES I THROUGH BOPE STACK. -WELL ON SLIGHT VACUUM. 1-STAND BACK 4-3/4"DRILL COLLARS. -PULL SPEAR WITH FISH AND PULL COMPLETELY OUT OF HOLE. -COMPLETE FISH RECOVERED. -VERIFY NO BLOCKAGE IN TAIL PIPE BY APPLYING STEAM INTO WLEG AND OBSERVING STEAM EXIT LIFTING SUB OF JAR. -BREAK OFF PACKER AND TAIL PIPE. *UNABLE TO DISENGAGE SPEAR FROM PACKER. **ALL EQUIPMENT PULLED FROM WELL HAS BEEN NORMED AND IS FREE OF RADIOACTIVITY. 08:30 - 09:30 1.00 1 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR. -PJSM,BEAVER SLIDE OPERATIONS. --CLEAR FLOOR OF ALL TOOLS AND EQUIPMENT NOT NEEDED. -MOBILIZE 7-5/8"SCRAPER AND POLISH MILL ASSY BHA TO RIG FLOOR. 09:30 - 11:00 1.50 FISH P DECOMP !RIH WITH 7-5/8"SCRAPER AND POLISH MILL ASSEMBLY -PJSM,MAKE UP 7-5/8"SCRAPER AND POLISH MILL ASSY.BHA AND RIH T/345'. 11:00 - 13:00 2.00 FISH P DECOMP PJSM,RIH WITH 7-5/8"SCRAPER AND POLISH ,MILL ASSEMBLY. -1R11-1F/345'T/3,950'WITH 4"DRILL PIPE FROM DERRICK. *LOSSES FOR 12 HOUR TOUR=10 BBLS. *-OA WAS OPEN TO FLOW BACK TANK SINCE 13:55 ON 06/12/2013 WITH NO FLUIDS OBSERVED IN PREPARATION FOR PACK-OFF CHANGE OUT.SHUT IN OAAT 12:00. 13:00 - 14:00 1.00 FISH P DECOMP 1SCRAPE 7-5/8"CASING FOR UPCOMING TIE BACK SETTING DEPTH OF 7-5/8 X 5-1/2""ZXP" LINER TOP PACKER. -ESTABLISH PARAMETERS. -CIRCULATE AT 5 BBLS WITH 430 PSI AND 40 RPM WITH 1K TORQUE. -PUW 115K,SOW 120K,ROT WT 120K. -RECIPROCATE,ROTATE AND PUMP WHILE SCRAPING F/3,940'T/4,060'. -REAM AND ROTATE 3 TIMES. *FIRE DRILL HELD. 14:00 - 16:00 2.00 FISH P DECOMP RIH WITH 7-5/8"SCRAPER AND POLISH MILL ASSEMBLY. -RIH F/4,144'T/8,607'WITH 4"DRILL PIPE FROM DERRICK. Printed 7/8/2013 10:06:11AM f North America-ALASKA-BP 7, Operation Summary Report;` Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X400X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 17:00 1.00 FISH P DECOMP DRESS TOP AND INSIDE OF TIE BACK RECEPTACLE FOR UPCOMING 5-1/2"TIE BACK ASSEMBLY. -ESTABLISH PARAMETERS. -PUW 195K,SOW 156K,ROT WT 175K. -RIH AND TAG UP AT 8,695'WITH"TBR" PLACING TOP DRESS MILLAT 8,690'WITH PUMPS OFF AND NO ROTATION. I-PULLED UP TO 8,690'WITH"TBR"POLISHING MILL PLACING TOP DRESS MILL AT 8,685'. -CIRCULATE AT 5 BPM WITH 570 PSI AND 60 RPM WITH 3-4KTORQUE. -WASH DOWN AND POLISH TIE BACK RECEPTACLE. -PUT 3K ON MILL,PULL UP AND INCREASE WEIGHT ON MILL TO 5K. -PULL UP AND INCREASE WEIGHT ON MILL 'TO7K. -PUMPS AND ROTARY OFF. I-VERIFY"TBR"SLICK. -RIH AND TAG"TBR"AT 8,695'PLACING TOP DRESS MILLAT 8,690'. 17:00 - 18:00 1.00 FISH P DECOMP PUMP HIGH VIS SWEEP SURFACE TO SURFACE. -CIRCULATE AT 5 BPM WITH 580 PSI. -ONCE SWEEP EXITED MILL INCREASED PUMP RATE TO 10 BPM WITH 1,950 PSI. -PUMPS AND ROTARY OFF. -RIH AND TAG UP AT 8,695 WITH"TBR" PLACING TOP DRESS MILL AT 8,690'. -STAND BACK 1 STAND OF 4"DRILL PIPE T/ 8,607'. 18:00 - 22:00 4.00 FISH P DECOMP PJSM ON DUMPING 800 LBS OF RIVER SAND DOWN THE DRILL PIPE. -LINE UP FOR DUMPING 800 LBS OF RIVER SAND WITH 9.8 BRINE ATTACHED TO SAND HOPPER. -DUMP 16 SACKS OF RIVER SAND AT SLOW RATE WITH HIGH VOLUME OF BRINE DUE TO 1.25"ID OF SCRAPER AND 3 STACKED BOOT BASKETS WITH 1-1/2"ID EACH. *SIM OPS-CLEAR RIG FLOOR FROM TOOLS NOT NEEDED,CLEAN MUD PUMP SUCTION LINES AND OFF LOAD 9.8 BRINE INTO PITS. -WAIT 30 MINUTES FOR SAND TO SETTLE. 22:00 - 23:00 1.00 FISH P DECOMP CLEAR 4"DRILL PIPE AND SCRAPER BHA OF ANY RESIDUAL SAND. -MAKE UP TOP DRIVE AND CIRCULATE DRILL STRING VOLUME AT 3 BPM W/200 PSI. 23:00 - 23:30 0.50 FISH P DECOMP RIH TO TAG SAND. -RIH F/8,607'T/8,665'AND TAG SAND. -P/U AND SCREW INTO TOP DRIVE TO PUMP. Printed 7/8/2013 10:06:11AM • North America-ALASKA BP %i ), r Operation Summary Report'; Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00.00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UW: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 FISH P DECOMP WASH OUT SAND FROM TIE BACK RECEPTACLE. -MAKE UP TOP DRIVE AND ESTABLISH PARAMETERS. -PUMP 12 BPM WITH 2,850 PSI AT 60 RPM W/ 3K FREE TORQUE. -WASH DOWN TO 8,695'. `Q BBL LOSS FOR 12 HOUR TOUR. *OUTER ANNULUS PRESSURE=0 PSI. **BARRIERS ARE COMPOSITE PLUG AT 8,800', TQP OF RIVER SAND AT 8,695',FULL HOLE OF 9.8 PPG,KWF,TESTED BOPE,DOUBLE CASING VALVES. 6/15/2013 00:00 - 01:00 1.00 FISH P DECOMP CIRCULATE HIVIS'SWEEP SURFACE TO SURFACE AT 12 BPM W/2800 PSI.WHILE RECIPROCATING F/8,680'T/8,607' 'SAND SEEN BACK AT THE SHAKERS JUST AHEAD OF HI-VIS SWEEP. -SI(UT DOWN PUMPS AND DRY TAG"TBR"AT 8,695`WITH POLISH MILL PLACING TOP DRESS MILL AT 8,690'. FLAW CHECK WELL FOR 10 MINS. 01:00 - 04:00 3.00 FISH P _ DECOMP POOH WITH 7-5/8"SCRAPER AND TIE BACK "RECEPTACLE POLISH MILLASSEMBLY. -PJSM,STAND BACK 4"DRILL PIPE F/8,695'T/ 8,607'. -BLOW DOWN TOP DRIVE. -POOH STANDING BACK 4"DRILL PIPE F/ 8,607'T/440'. -FLOW CHECK WELL BEFORE PULLING NON SHEARABLES THROUGH BOPE STACK 04:00 - 04:30 0.50 FISH P DECOMP POOH WITH 7-5/8"SCRAPER AND TIE BACK RECEPTACLE POLISH MILL ASSEMBLY BHA. -STAND BACK LAST STAND OF 4"DRILL PIPE F/440'T/345'. 04:30 - 06:00 1.50 FISH P DECOMP -PJSM,LAY DOWN 9 4-3/4"DRILL COLLARS AND 7-5/8"SCRAPER WITH"TBR"DRESS AND POLISH ASSEMBLY WITH BOOT BASKETS AND MAGNETS. -TATTLE TALES ON DRESS OFF AND POLISH ASSEMBLY INDICATE SUCCESSFUL DRESSING OF TIE BACK RECEPTACLE. `LOSSES ARE CURRENTLY 6.5 BBLS.OVER PIPE DISPLACEMENT. "BARRIERS ARE COMPOSITE PLUG AT 8,800', TOP OF RIVER SAND AT 8,695',FULL HOLE OF 9.8 PPG KWF,TESTED BOPE,DOUBLE CASING VALVES. 06:00 - 07:30 1.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR OF ALL TOOLS AND EQUIPMENT NOT NEEDED FOR UPCOMING OPS. -PJSM.BEAVER SLIDE OPS. 07:30 - 08:00 0.50 DHB P DECOMP MAKE UP BAKER 5-1/2"PACK-OFF AND HES 7-5/8"RTTS BHA. -PJSM WITH SERVICE REPS AND DOYON REPS. 08:00 - 10:00 2.00 DHB P DECOMP RIH WITH 4"DP FROM DERRICK. -PJSM,RIH F/32'T/3,072'. 10:00 - 13:30 3.50 DHB N WAIT 3,072.00 DECOMP SAFETY STAND DOWN. *8 BBLS.LOSS FOR 12 HOUR TOUR. Printed 7/8/2013 10•06:11AM r y ry, • , North America-ALASKA BPS %' Operation Summary Report Common Well Name:02-27 i AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 IX4-OOX8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM I Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) - 13:30 - 14:30 1.00 DHB N WAIT 3,072.00 DECOMP PJSM WITH HES SERVICE REPS AND DOYON PERSONNEL ON SETTING 7-5/8"RTTS. 14:30 - 15:00 0.50 DHB N WAIT 3,072.00 DECOMP I SET 7-5/8"RTTS CENTER OF ELEMENT AT 3,048'. -CIRCULATE AIR OUT OF SURFACE SYSTEM AND CLOSE UPPER VBR. 15:00 - 18:00 3.00 DHB N WAIT 3,072.00 DECOMP PRESSURE TEST 7-5/8"CSG WITH RTTS FROM 3,048'TO SURFACE. -TEST 250 PSI LOW FOR 5 MINUTES AND 3000 PSI HIGH. CHART AND RECORD PSI FOR 45 MINUTES. -CONFIRM TEST RESULTS WITH WTL. -BLEED PRESSURE OFF AND OPEN UPPER j VBR. -CIRCULATE OVER TOP OF HOLE WITH CHARGE PUMP. 18:00 - 00:00 6.00 DHB N WAIT 3,072.00 DECOMP MONITOR LOSSES AND FILL WELL UNDER THE 7-5/8"RTTS EVERY HOUR THROUGH THE DRILL PIPE. -INSTALL 4"XT-39 FOSV IN DRILL PIPE. -MAKE UP TOP DRIVE TO SERVE AS A SECONDARY BARRIER FOR WELL CONTROL. -CHECKING FOR PRESSURE EVERY HOUR AND BREAKING OUT TOP DRIVE AND FILLING WITH FILL UP LINE THROUGH XT-39 FOSV. -CIRCULATE OVER TOP OF HOLE WITH CHARGE PUMP. *6.5 BBLS.LOSS FOR 12 HOUR TOUR. **14.5 BBLS.TOTAL LOSS FOR PAST 24 I HOUR. ***BARRIERS ARE COMPOSITE PLUG AT 1 8,800',TOP OF RIVER SAND AT 8,695',FULL HOLE OF 9.8 PPG KWF,TESTED 7-5/8"RTTS AT 3,048',TESTED BOPE,DOUBLE CASING VALVES,TESTED 4"XT-39 FOSV,TESTED LOWER KELLY VALVE ON TOP DRIVE. 6/16/2013 00:00 - 06:00 6.00 DHB N WAIT 3,048.00 DECOMP SAFETY STAND DOWN. MONITOR LOSSES AND FILL WELL UNDER THE 7-5/8"RTTS EVERY HOUR THROUGH THE DRILL PIPE. I-MAKE UP TOP DRIVE TO SERVE AS A SECONDARY BARRIER FOR WELL CONTROL. 1-CHECKING FOR PRESSURE EVERY HOUR BREAKING OUT TOP DRIVE AND FILLING WITH FILL UP LINE THROUGH 4"XT-39 FOSV. -CIRCULATE OVER TOP OF HOLE WITH I CHARGE PUMP WITH NO LOSSES TO HOLE ABOVE 7-5/8"RTTS AT 3,048'. *3 BBL.LOSS FOR LAST 6 HOURS. **BARRIERS ARE COMPOSITE PLUG AT 8,800', TOP OF RIVER SAND AT 8,695',FULL HOLE OF 9.8 PPG KWF,TESTED 7-5/8"RTTS AT 3,048', TESTED BOPE,DOUBLE CASING VALVES, TESTED 4"XT-39 FOSV,TESTED LOWER KELLY VALVE ON TOP DRIVE. ***TABLE TOP H2S DRILL,MAN DOWN DRILL I AND RIG EVAC DRILL. Printed 7/8/2013 10:06:11AM i ! North America-ALASKA-BP Operation Summary Report`, Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 00:00 18.00 DHB N WAIT 3,048.00 DECOMP SAFETY STAND DOWN. MONITOR LOSSES AND FILL WELL UNDER THE 7-5/8"RTTS EVERY TWO HOURS THROUGH THE DRILL PIPE. -MAKE UP TOP DRIVE TO SERVE AS A SECONDARY BARRIER FOR WELL CONTROL. -CHECKING FOR PRESSURE EVERY TWO HOURS BREAKING OUT TOP DRIVE AND FILLING WITH FILL UP LINE THROUGH 4" XT-39 FOSV. -CIRCULATE OVER TOP OF HOLE WITH CHARGE PUMP WITH NO LOSSES TO HOLE ABOVE 7-5/8"RTTS AT 3,048'. *AOGCC NOTIFICATION OF INTENT TO PERFORM WEEKLY BOPE TEST. *NOTIFIED VIA WEBSITE NOTIFICATION FORM SUBMITTED AT 07:30 HOURS. *JEFF TURKINGTON RESPONDED BACK WAIVING WITNESS OF TEST. *OUTER ANNULUS PRESSURE=0 PSI. *TOTAL OF 13 BBL LOSS FOR LAST 24 HOURS. **BARRIERS ARE COMPOSITE PLUG AT 8,800', TOP OF RIVER SAND AT 8,695',FULL HOLE OF '9.8 PPG KWF,TESTED 7-5/8"RTTS AT 3,048', TESTED BOPE,DOUBLE CASING VALVES, TESTED 4"XT-39 FOSV,TESTED LOWER KELLY VALVE ON TOP DRIVE. ***SPILL DRILL,TABLE TOP ACCUMULATOR DRILL,RIG EVAC DRILL,FIRE DRILL,MAN DOWN DRILL AND CAMP FIRE/EVAC DRILL. 6/17/2013 00:00 14:00 14.00 DHB N WAIT 3,048.00 DECOMP I SAFETY STAND DOWN. MONITOR LOSSES AND FILL WELL UNDER THE 7-5/8"RTTS EVERY TWO HOURS THROUGH THE DRILL PIPE. -MAKE UP TOP DRIVE TO SERVE AS A SECONDARY BARRIER FOR WELL CONTROL. I-CHECKING FOR PRESSURE EVERY TWO HOURS AND BREAKING OUT TOP DRIVE AND FILLING WITH FILL UP LINE THROUGH 4" XT-39 FOSV. -CIRCULATE OVER TOP OF HOLE WITH CHARGE PUMP WITH NO LOSSES TO HOLE ABOVE 7-5/8"RTTS AT 3,048'. I*6.5 BBL.LOSS FROM MIDNIGHT TO NOON. **BARRIERS ARE COMPOSITE PLUG AT 8,800', TOP OF RIVER SAND AT 8,695',FULL HOLE OF 9.8 PPG KWF,TESTED 7-5/8"RTTS AT 3,048', TESTED BOPE,DOUBLE CASING VALVES, I TESTED 4"XT-39 FOSV,TESTED LOWER I KELLY VALVE ON TOP DRIVE. *SPILL DRILL. 14:00 - 15:00 1.00 DHB N WAIT 3,048.00 DECOMP MEETING WITH DOYON HSE AND BP REPS TO DISCUSS GOING BACK TO WORK EXPECTATIONS. -REVIEW COWS,SOP'S,PROCEDURES AND POLICIES. i 15:00 - 16:00 1.00 DHB P DECOMP—TSERVICE TOP DRIVE,INSPECT DERRICK, GREASE CHOKE VALVES. Printed 7/8/2013 10:06:11AM • • North America-ALASKA-BP '' � f'Operation Summary Report Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 17:30 1.50 DHB P DECOMP PJSM WITH HALLIBURTON REPS ON UNSETTING 7-5/8"RTTS. -UNSET 7-5/8"RTTS AS PER HES SOP. PUW 95K,SOW 96K. PJSM,CIRCULATE BOTTOMS UP. -LINE UP AND CIRCULATE 7 BPM W/300 PSI. -OBTAIN SLOW PUMP RATES. --FLOW CHECK FOR 10 MINUTES-WELL ON SLIGHT VACUUM. '-PJSM,BLOW DOWN THE TOP DRIVE. 17:30 - 18:30 1.00 DHB P DECOMP PJSM,POOH WITH 7-5/8 RTTS AND 5-1/2" PACK-OFF ASSEMBLY. -STAND BACK 4"DRILL PIPE F/3,052'T/32'. 18:30 - 19:30 1.00 DHB P DECOMP PJSM,L/D 7-5/8"HES RTTS WITH BAD ELEMENT. -PJSM,REMOVE RTTS FROM RIG FLOOR THROUGH BEAVER SLIDE. 19:30 - 21:00 1.50 BOPSUR - DECOMP PJSM,DRAIN STACK AND REMOVE WEAR BUSHING. 21:00 - 00:00 3.00 BOPSUR P DECOMP PJSM,WEEKLY BOPE TEST. -INSTALL TEST PLUG WITH 2-7/8"TEST JOINT. -R/U TEST EQUIPMENT. -R/U 4"FOSVS AND 3-1/2"IF FOSV. —PERFORM ACCUMMULATOR DRAW DOWN TEST. -TEST ANNULAR PREVENTER WITH 2-7/8" TEST JOINT 250 PSI LOWAND 3500 PSI HIGH FOR 5 MINUTES. *WELL KILL DRILL-TOOK 6 BBLS TO FILL U-TUBE AND MGS VESSEL BEFORE RETURNS WERE SEEN AT PITS. *6 BBL.LOSS FROM NOON TO MIDNIGHT. *TOTAL OF 12.5 BBL.LOSS FOR LAST 24 HOURS. *OUTER ANNULUS PRESSURE=0 PSI. **GRAVITY FEEDING IA AT.5 BPH. **WEEKLY BOPE TEST WITNESS WAIVED BY AOGCC REP JEFF TURKINGTON. 6/18/2013 00:00 - 10:30 10.50 BOPSUR P DECOMP PERFORM WEEKLY BOPE TEST TO 250 PSI. LOWAND 3,500 PSI.HIGH FOR 5 CHARTED MINUTES EACH. -TEST LOWER 2-7/8"X 5"VBR W/2-7/8"AND 4"TEST JOINTS -TEST UPPER 3-1/2"X 6"VBR W/ 3-1/2"AND 5-1/2"TEST JOINTS. -TEST TWO 4"XT 39 FOSV AND ONE 3-1/2"IF FOSV. -TEST ONE 4"XT 39 DART VALVE ALONG WITH UPPER AND LOWER KELLY VALVES ON TOP DRIVE. *OUTER ANNULUS PRESSURE=0 PSI. **GRAVITY FEEDING IA AT.5 BPH. **WEEKLY BOPE TEST WITNESS WAIVED BY AOGCC REP JEFF TURKINGTON. 10:30 - 11:00 0.50 BOPSUR P DECOMP PJSM,PULL TEST PLUG AND INSTALL WEAR BUSHING. 11:00 - 12:00 1.00 BOPSUR P DECOMP PJSM,BLOW DOWN TOP DRIVE,CHOKE AND KILL LINES. -R/D ALL TEST EQUIPMENT. *OUTER ANNULUS PRESSURE=0 PSI. *6 BBL LOSS FROM MIDNIGHT TO NOON. Printed 7/8/2013 10:06:11AM • orth America-ALASKA `� ; %" r Opera tion Summary Re.," Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations I (hr) (usft) —12:00 - 15:00 3.00 BOPSUR P DECOMP PJSM,M/U SAFETY JOINT. -BEAVER SLIDE OPERATIONS,MOBILIZE HES I7-5/8"RTTS AND BAKER 5-1/2"PACK-OFF TO RIG FLOOR. -INSPECT DERRICK,ADD GEAR OIL TO TOP DRIVE. 15:00 - 16:00 1.00 I DHB P DECOMP PJSM,W/HES REPS AND DDI CREW ON MAKING UP HES 7-5/8"RTTS. 16:00 - 19:30 3.50 DHB P ■ DECOMP 1PJSM,RIH W/HES RTTS ON 4"DP FROM THE I DERRICK. -RIH F/62'T/6,407'. 19:30 - 20:00 0.50 DHB P DECOMP PJSM SET AND TEST LINER TOP AT 8,690' I AND PLUG AT 8,800'WITH 7-5/8"RTTS. -OBTAIN PARAMETERS,PUW 145K,SOW 135K. -RIH T/6,500',PULL UP TO 145K. -TURN 2 TURNS TO THE RIGHT AND HOLD TORQUE. -SLACK OFF PAST 135K AND RELEASE TORQUE. -SET DOWN 15K ON RTTS.AT 120K. -RTTS SET IN PLACE AT 6,500'CENTER OF FLEMENT. -SHUT ANNULAR PREVENTER AND CHARGE PUMP DOWN THE INNER ANNULUS TO CHECK RTTS CIRCULATE VALVE SHUT. -CONFIRMED CIRC VALVE SHUT WITH NO RETURNS OBSERVED THROUGH DRILL PIPE. -CONFIRM NO PRESSURE ON ANNULUS AND OPEN ANNULAR PREVENTER. 20:00 - 21:00 1.00 DHB P DECOMP RIG UP TO TEST LINER TOP AT 8,690'AND PLUG AT 8,800'THROUGH THE DRILL PIPE WITH RTTS SET AT 6,500'. -PRESSURE UP TO 2000 PSI.WITH 1.6 BBLS. -CHART AND HOLD FOR 30 MINUTES-TEST WAS GOOD. -BLEED OFF PRESSURE. 21:00 - 21:30 0.50 DHB P DECOMP RELEASE 7-5/8"RTTS AND FLOW CHECK WELL. -RELEASE 7-5/8"RTTS. -OBTAIN SLOW PUMP RATES. -FLOW CHECK FOR 10 MINUTES,WELL ON SLIGHT VACUUM. -BLOW DOWN TOP DRIVE. 211:30 22:30 1.00 DHB P ■- DECOMP POOH WITH 7-5/8"RTTS. PJSM,POOH F//6,502'T/4,508'STANDING BACK 4"DRILL PIPE. Printed 7/8/2013 10:06:11AM • • North America-ALASKA B '" Operation Summary Report.:,:. Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00.00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 00:00 1.50 DHB P DECOMP PJSM ON TESTING 7-5/8"CASING TO 3,000 PSI. -OBTAIN PARAMETERS,PUW 115K,SOW 115K. -PICK UP TO PUW WITH CENTER OF ELEMENT AT 4,500',2 TURNS TO THE RIGHT AND HOLD TORQUE. -SLACK OFF TO 95K WITH 20K ON RTTS AND RELEASE TORQUE. *RTTS SET IN PLACE AT 4,500'. -LINE UP THROUGH KILL LINE AND PURGE AIR FROM SURFACE SYSTEM. -CLOSE UPPER VBR. -PRESSURE UP TO 3,200 PSI.WITH 1.9 BBLS. PUMPED. *OAOPENED TO FLOW BACK TANK AT 22:45. *5 BBL LOSS FROM NOON TO MIDNIGHT. *TOTAL OF 11 BBL LOSS FOR LAST 24 HOURS. 6/19/2013 00:00 - 00:30 0.50 DHB P DECOMP TEST 7-5/8"CSG TO 3,000 PSI.FOR 30 CHARTED MINUTES. -BLEED DOWN PRESSURE 1 BBL BLED BACK. -CONFIRM NO PRESSURE ON ANNULUS AND bE'EN UPPER VBR. *CONFIRM TEST RESULTS WITH WTLAT 12:07 AM. 00:30 - 02:00 1.50 DHB P DECOMP PJSM,R/D TEST EQUIP. -PJSM,DRAIN STACK,BLOW DOWN CHOKE AND KILL LINE. -FILL HOLE WITH HOLE FILL PUMP. -RELEASE RTTS. -MONITOR WELL-WELL ON SLIGHT VACUUM. -STAND BACK 1 STAND OF 4"DRILL PIPE F/ 4,508'T/4,413'. 02:00 - 03:30 1.50 DHB P DECOMP PJSM,SLIP AND CUT 59'OF DRILLING LINE. -SERVICE AND INSPECT TOP DRIVE,BLOCKS AND CROWN. 03:30 - 04:00 0.50 DHB P DECOMP PREPARE RIG FLOOR FOR LAYING DOWN 4" DRILL PIPE. -PJSM,BEAVER SLIDE OPERATIONS. -REMOVE CUT DRILLING LINE FROM RIG FLOOR AND BRING IN 4"XT-39 THREAD PROTECTORS. 04:00 - 08:00 4.00 DHB P DECOMP POOH WITH 7-5/8"RTTS USED FOR TESTING LINER TOP AND 7-5/8"CASING. -POOH LAYING DOWN 4"DRILL PIPE F/4,413' T/1,500'. *OA REMAINS OPEN TO FLOW BACK TANK SINCE 22:45 ON 06/18/2013 WITH NO FLUIDS OBSERVED IN PREPARATION FOR PACK-OFF CHANGE OUT. *LOSSES REMAIN AT.5 BBL PER HOUR. 08:00 - 09:00 1.00 DHB P DECOMP PJSM,WITH HES SERVICE HAND TO UD RTTS. -CLEAN AND CLEAR RIG FLOOR OF ALL TOOLS AND EQUIPMENT NOT NEEDED. 09:00 - 10:30 1.50 TIEBAC P OTHCMP PJSM,BEAVER SLIDE OPERATIONS. -UD AND P/U BAILS,CENTRALIZER'S,TUBING TOOL BASKET,ELEVATORS AND SLIPS. -REMOVE SET SCREWS FROM CENTRALIZER'S. Printed 7/8/2013 10:06:11AM • • North America-ALASKAN . �` Operation Summary Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 14:00 3.50 TIEBAC P OTHCMP PJSM,RIG UP TO RUN 5-1/2"L-80 TC-II 17# -REMOVE TRIPPING BALES AND INSTALL CASING BALES. -INSTALL COMPENSATOR ON SAVER SUB OF TOP DRIVE. -INSTALL 5-1/2"YC ELEVATORS. -RIG UP 5-1/2 TUBING TONGS WITH -"INTEGRAL BACK UPS. -INSTALL COMPUTER TORQUE AND TURN DUMP VALVE SYSTEM. -RIG UP AND FUNCTION TEST STABBING BOARD. *8.5 BBL LOSS FROM MIDNIGHT TO NOON. 'OA REMAINS OPEN TO FLOW BACK TANK SINCE 22:45 ON 06/18/2013 WITH NO FLUIDS OBSERVED IN PREPARATION FOR PACK-OFF CHANGE OUT. 14:00 - 00:00 10.00 TIEBAC P OTHCMP PJSM,RIH W/5-1/2"L-80 IC-1117#LINER. -BAKER LOK CONNECTIONS BELOW THE JOINT OF 5-1/2"LINER THAT HAS THE INSERT LANDING COLLAR. -RIH F/99'T/4,676'PICKING UP 5-1/2"TC-II LINER FROM PIPE SHED. -MAKE UP TORQUE IS 5,500 FT/LBS WITH JET LUBE SEAL GUARD THREAD COMPOUND. -PUW 120K,SOW 120K. 'KICK WHILE TRIPPING DRILL. "6 BBL LOSS FROM MIDNIGHT TO NOON. *TOTAL OF 14.5 BBL LOSS FOR LAST 24 HOURS. *OA REMAINS OPEN TO FLOW BACK TANK SINCE 22:45 ON 06/18/2013 WITH NO FLUIDS OBSERVED IN PREPARATION FOR PACK-OFF CHANGE OUT. 6/20/2013 '00:00 - 00:30 0.50 TIEBAC P OTHCMP BEAVER SLIDE OPERATIONS. -PICK UP 3-1/2"DRILL PIPE ELEVATORS AND 3-1/2"SLIPS FOR PUP JOINT ON"ZXP" HANGER/PACKER ASSEMBLY. -CHANGE OUT ELEVATORS F/5-1/2"YT T/ 3-1/2"DRILL PIPE. 00:30 - 01:30 1.00 TIEBAC P OTHCMP PJSM,PICK UP AND RIH WITH 7-5/8"X 5-1/2" "ZXP"LINER TOP HANGER/PACKER. -CHANGE OUT ELEVATORS F/5-1/2"YT T/ 3-1/2"DRILL PIPE. -PICK UP PACKER WITH 3-1/2"HANDLING SUB MAKE UP AND RIH T/4,717'. 01:30 - 02.00 0.50 TIEBAC P OTHCMP PJSM,PICK UP 4"SAFETY JOINT AND RIH T/ 4,747'. -CHANGE OUT ELEVATORS F/3-1/2"T/4". -PICK UP SAFETY JOINT F/PIPE SKATE AND RIH TO PLACE SHEARABLES ACROSS STACK. 02:00 - 02:30 0.50 TIEBAC P OTHCMP PJSM,RIG DOWN CASING RUNNING EQUIPMENT. -REMOVE 4"ELEVATORS AND CASING BALES FROM TOP DRIVE. -REMOVE 5-1/2"SINGLE JOINT ELEVATORS. -BREAK OUT COMPENSATOR ASSEMBLY. II, Printed 7/8/2013 10:06:11AM • • :. _ North America-ALASKA BPP Operation Summary Repor z° Common Well Name:02-27 1AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 03:30 1.00 TIEBAC OTHCMP PJSM FOR BEAVER SLIDE OPERATIONS AND INSTALLING TRIP BALES. -REMOVE CASING BALES FROM RIG FLOOR AND PICK UP TRIPPING BALES. -INSTALL TRIP BALES ON TOP DRIVE AND ASSEMBLE LINK TILT ARMS. -INSTALL 4"DRILL PIPE ELEVATORS. 03:30 - 04:00 0.50 TIEBAC OTHCMP PJSM ON CIRCULATING LINER VOLUME. '-LINE UP AND CIRCULATE THROUGH LINER TAKING RETURNS TO PITS. .PUMP AT 3 BPM WITH 120 PSI.TOTAL OF 110 BBLS PUMPED. 04:00 - 05:30 1.50 TIEBAC P OTHCMP PJSM,REMOVE 5-1/2"CASING TONGS AND CASING EQUIPMENT FROM RIG FLOOR. -SECURE AIR HOSE FROM COMPENSATOR IN DERRICK. 05:30 - 10:00 4.50 TIEBAC P OTHCMP PJSM,RIH WITH 5-1/2"TIE BACK ASSEMBLY Fl 4,717'T/8,695'. -PULL 4"SAFETY JOINT FROM STRING AND LAY DOWN IN PIPE SHED. -RIH DRIFTING 4"DRILL PIPE FROM DERRICK WITH 5-1/2"TIE BACK STRING F/4,717 T/ 8,695". . -TAG TOP OF PBR AT 8,695'. 10:00 - 11:00 1.00 TIEBAC P OTHCMP PJSM,ESTABLISH PARAMETERS 1-PUW 185K,SOW 157K. PUMP.5 BBLS A MINUTE WITH 30 PSI. -SET DOWN 7K,TROUBLE GETTING INTO BORE RECEPTACLE. -P/U TO 175K AND TURN TO THE LEFT 1/2 TURN AND SET DOWN 12K. -INCREASE PUMP TO 1.5 BBLS PER MINUTE WITH 60 PSI. -SET 10K AND TURN 1/2 TURN TO THE LEFT. -GO DOWN AND WORK SEVERAL TIMES UNTIL SEALASSEMBLY WORKED INTO PBR. PRESSURE UP,PUMPS OFF,GO DOWN AND SET 25K.MARK STRING AT NO GO 8,695' TOP OF PBR) -SEAL ASSEMBLY MULE SHOE AT 8,700'AT NO GO. -SEALS LOCATED. 11:00 - 13:30 2.50 TIEBAC P OTHCMP PJSM,BLOW DOWN TOP DRIVE. I-P/U CEMENT HEAD. -M/U CEMENT HEAD ON DRILL STRING AND TORQUE TO SPECS. *0 BBL FLUID LOSS FROM MIDNIGHT TO NOON. 13:30 - 15:30 i 2.00 TIEBAC P OTHCMP PJSM,PICK UP ON DRILL STRING AND EXPOSE CIRCULATION PORTS. -PICK UP TO PUW 187K. -PRESSURE UP TO 500 PSI. -PICK UP STRING UNTIL PRESSURE DROPS OFF,6'PICK UP. -SHUT DOWN AND ESTABLISH CIRCULATION. -CIRCULATE 5 BARRELS PER MINUTE WITH 580 PSI. it Printed 7/8/2013 10:06:11AM • • arth America-ALASKA BPS } ; "`. y Operation Summary Report Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X400X8D-E:(3,200,000.00) Project:Prudhoe Bay I Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 18:30 3.00 TIEBAC P OTHCMP PJSM ON CEMENTING 5-1/2"LINER. -SLB PUMP 5 BBL WATER. -PRESSURE TEST LINES TO 250 PSI LOWAND 4500 PSI HIGH FOR 5 MINUTES EACH-TESTS GOOD. -PUMP 100 BBLS 15.8 PPG CLASS G CEMENT. -START PUMP RATE AT 1.2 BPM W/114 PSI., AFTER 3.6 BBL OF CEMENT AWAY BRING I PUMP RATE UP TO 3.8 BPM W/664 PSI., AFTER 7.7 BBL OF CEMENT AWAY SLOW PUMPS TO 3 BPM W/320 PSI.,AFTER 24 BBL I OF CEMENT AWAY BRING PUMPS UP TO 4.7 BPM W/627 PSI.,AFTER 94 BBL OF CEMENT 1 AWAY PUMPING AT 4.9 BPM W/682 PSI. SLOWED PUMPS DOWN AND AFTER 100 BBL OF CEMENT AWAY SHUT DOWN PUMP W/50 PSI. -DROP DART AND CHASE WITH 9.8 PPG 1 BRINE. I -CHASE WITH 5 BBL OF WATER AT 5 BPM W/ 270 PSI.,PUMP 9.8 BRINE AT 5 BPM W/270 PSI.AFTER 33 BBLS TOTAL AWAY SLOW PUMPS TO 3 BPM W/120 PSI.AFTER 54 BBLS .AWAY BROUGHT PUMP RATE UP TO 5 BPM W/ 280 PSI.CAUGHT CEMENT AFTER 79 BBLS PUMPING AT 5 BPM W/570 PSI.,SLOWED PUMPS TO 3 BPM W/1,648 PSI AFTER 127 BBLS AWAY,SLOWED TO 2 BPM W/1,790 PSI AFTER 137 BBLS AWAY.BUMPED PLUG WITH 150 BBL OF TOTAL DISPLACEMENT.5 BBLS OF WATER AND 145 BBLS OF 9.8 BRINE. -DID NOT SEE DP WIPER PLUG LATCH INTO LINER WIPER PLUG.(NO PRESSURE INCREASE) -CEMENT IN PLACE AT 17:31. -ENGAGE SEALS AS PER BAKER REPS INSTRUCTIONS. I -SLACK OFF TO FULLY ENGAGE SEAL 1 ASSEMBLY AT 8,700'. -SET HANGER IN PLACE. -PRESSURE UP TO 3,000 PSI HOLDING, PRESSURE UP TO 4,200 PSI.OBSERVED SHEAR AT 3,400 PSI.BLEED PSI.OFF. -SET ZXP LINER TOP PACKER AND UN STING. -PICK UP TO 170K SLACK OFF TO 145K. -TURN TO RIGHT WITH TOP DRIVE 5 TURNS GET BACK 4. 1 -SLACK OFF TO 105K. -TURN TO RIGHT WITH TOP DRIVE 5 TURNS AND GET NO TURNS BACK,REPEAT TWO MORE TIMES. -PICK UP TO CONFIRM RELEASE, RELEASED AT 115K UP. -PRESSURE UP TO 500 PSI.AND HOLD WHILE PICKING UP TO CLEAR PACK OFF. -SLB CIRCULATE 50 BBLS OF 9.8 BRINE AT 8 BPM W/1,250 PSI.TO CLEAN CEMENT OFF OF LINER TOP. -RIG DOWN CEMENT LINE FROM CEMENT HEAD. -SET LINER TOP PACKER. 1 I -ROTATE AT 10 RPM 130K ROTATING 1 I I Printed 7/8/2013 10:06:11AM • i North America-ALASKA B Operation Summary Re• • Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) WEIGHT,SLACK OFF AND SET DOWN 55K, OBSERVED SHEAR AT 36K. -TURN OFF ROTATION PICK UP TO 110K UP WEIGHT. 18:30 - 19:00 0.50 TIEBAC P OTHCMP CIRCULATE 8 BPM WITH 620 PSI. -CEMENT TO SURFACE AT 67 BBLS PUMPED. -SOLID CEMENT RETURNS FOR 90 BBLS -'PUMPED.TOTAL OF 23 BBLS OF CEMENT SEEN AT SURFACE. -WELL CLEANED UP COMPLETELY AFTER 108 BBLS PUMPED. -RETURNS BACK TO PITS AFTER 118 BBLS PUMPED. -CLEAN OUT WELL BORE UNTIL CLEAN. 19:00 - 20:00 1.00 TIEBAC P ® OTHCMP PJSM,RIG DOWN CEMENT HEAD. -BLOW DOWN TOP DRIVE. 20:00 - 22:00 2.00 TIEBAC P OTHCMP POOH WITH 5-1/2"LINER RUNNING TOOL PJSM,POOH Fl 4,b19'T/32'STANDING BACK 4"DRILL PIPE. 22:00 - 22:30 0.50 TIEBAC P OTHCMP PJSM,LAY DOWN LINER RUNNING TOOL. 22:30 - 00:00 1.50 BOPSUR P OTHCMP PJSM,FLUSH BOPE STACK CIRCULATE 10 BBLS PER MINUTE W/60 PSI AND 70 RPM WITH 0 TORQUE. -LAY DOWN STACK WASHER. *0 BBL FLUID LOSS FROM NOON TO MIDNIGHT. *OA REMAINS OPEN TO FLOW BACK TANK SINCE 22:45 ON 06/18/2013. 6/21/2013 00:00 - 01:00 1.00 BOPSUR P -- OTHCMP PJSM,PULL WEAR BUSHING. -DRAIN BOPE STACK. -ENGAGE WEAR BUSHING WITH RETRIEVING TOOL. -BACK OUT LOCK DOWN SCREWS. -PULL WEAR BUSHING. 01:00 - 02:00 1.00 WHSUR P OTHCMP PJSM,REPLACE 10-3/4"X 7-5/8"PACK-OFF. -ENGAGE PACK OFF THROUGH BOP STACK -ENSURE BLEEDER OPEN AND BACK OUT LOCK DOWN SCREWS. -PULL PACK-OFF TO RIG FLOOR AND INSTALL NEW PACK-OFF ON RUNNING TOOL AND MARK WITH PAINT STICK -LOWER PACK-OFF INTO PLACE,SET 1K DOWN WITH TOP DRIVE AND CONFIRM SET WITH VISUAL OF MARK THROUGH IA VALVES. RUN IN LOCK DOWN SCREWS. 02:00 03:00 1.00 WHSUR P OTHCMP TEST 10-3/4"X 7-5/8"PACK-OFF ASSEMBLY. -RIG UP CHART RECORDER TO RIG FLOOR AND PURGE VOID. -TEST SEALS AND VOID TO 5,000 PSI.AS PER FMC SOP. -PRESSURED UP TO 5,180 PSI.,AFTER 15 MINUTES SHOWED 5,080 PSI.,AFTER 30 MINUTES SHOWED 5,040 PSI. -GOOD TEST. *SHUT OA BACK IN. 03:00 - 03:30 0.50 CLEAN P ■- RUNCMP BRING U IN IC CLEAN S T ROUGHLBEAV HYDRAULIC TONGS THROUGH BEAVER SLIDE. Printed 7/8/2013 10:06:11AM North America-ALASKA- '7,341040:0W4Xkc Operation Summary Report . g • Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X400X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00.00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 04:00 0.50 BOPSUR P RUNCMP PJSM,INSTALL WEAR BUSHING. -SET WEAR BUSHING IN WELLHEAD PROFILE. -RUN IN LOCK DOWN SCREWS. *ID OF WEAR BUSHING IS 7-1/16". 04:00 - 05:00 1.00 CLEAN P RUNCMP PJSM,RIG UP FLOOR FOR RUNNING 2-7/8" PAC. -HOOK UP 4-1/2"ECKEL HYDRAULIC TONGS. -INSPECT SLIPS,ELEVATORS,DOG COLLAR AND LIFTING NUBBINS. -INSTALL ELEVATORS ON TOP DRIVE BALES. _ 05:00 - 09:30 4.50 CLEAN P RUNCMP PJSM,PICKING UP AND MAKING UP 5-1/2" LINER CLEAN OUT ASSEMBLY. -PICK UP 3-1/8"DRILL COLLAR AND INSTALL JAR,BIT SUB AND 4-3/4"BIT. -RIFT WITH 5-1/2"LINER CLEAN OUT ASSEMBLY TO 2,366'. 09:30 - 10:00 0.50 CLEAN P RUNCMP KICK DRILL AND AAR MEETING. *RESPONSE TIME OF 1 MINUTE 15 SECONDS. 10:00 - 11:00 1.00 CLEAN P RUNCMP BP MANDATED MEETING W/DDI CREW ABOUT OPERATIONS. *D&C OPERATIONS MANAGER,RWO WTL, - CTD WTLAND RWO/CTD SUPT. 11:00 - 12:00 1.00 CLEAN P RUNCMP PJSM,P/U AND M/U HT14(BABY MANUAL TONGS). -BEAVER SLIDE OPERATIONS. *0 BBL FLUID LOSS FROM MIDNIGHT TO NOON. 12:00 - 14:00 2.00 CLEAN P RUNCMP PJSM,RIH WITH 5-1/2"CLEAN OUT ASSEMBLY ON 2-7/8"PAC DRILL PIPE. -PICKING UP SINGLES FROM PIPESHED WITH LIFTING NUBBINS T/3,495'. 14:00 - 15:30 1.50 CLEAN P RUNCMP *KICK DRILL AND AAR MEETING. -BP MANDATED MEETING WITH DDI CREW. 15:30 - 16:00 0.50 CLEAN P RUNCMP PJSM,RIH WITH 5-1/2"CLEAN OUT ASSEMBLY ON 2-7/8"PAC DRILL PIPE. -PICKING UP SINGLES FROM PIPESHED WITH LIFTING NUBBINS T/3,867'. 16:00 - 18:00 2.00 CLEAN P RUNCMP DEVELOP SOP FOR USING HYDRAULIC POWER TONGS WITH INTEGRAL BACK UPS. -HAZARD RECOGNITION WORK SHEET APPROVED BY WSL. 18:00 - 21:00 3.00 CLEAN P RUNCMP PJSM,RIH WITH 5-1/T CLEAN OUT ASSEMBLY ON 2-7/8"PAC DRILL PIPE. -PICKING UP SINGLES FROM PIPESHED F/ 3,867'T/5,235'. *KICK WHILE TRIPPING DRILL,3 MINUTES FORTY EIGHT SECONDS RESPONSE TIME. AAR. 21:00 - 21:30 0.50 CLEAN P RUNCMP PJSM,CHANGE OUT ELEVATORS TO P/U 4" DP. -TAKE OFF CROSSOVERS FOR SAFETY VALVE AND INSTALL IN STRING. 21:30 - 22:30 1.00 CLEAN P RUNCMP PJSM,RIH WITH 5-1/2"CLEAN OUT ASSEMBLY. -RIH WITH 4"DRILL PIPE OUT OF THE DERRICK F/5,235'T/8,468'. *TAG CEMENT AT 8,563'. Printed 7/8/2013 10:06:11AM • . North America-ALASKA-BP ;rfU ,,F tit Operation Summary Report Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) I I Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12.00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 23:00 0.50 CLEAN P RUNCMP PJSM,MAKE UP TOP DRIVE AT 8,468'. -ESTABLISH PARAMETERS. -PUW 155K,SOW 130K.3 BPM W/1,250 PSI. -WASH DOWN F/8,468'T/8,563'. *TAG CEMENT AT 8,563'. -POOH F/8,563'T/8,468' 23:00 - 00:00 1.00 CLEAN P RUNCMP PJSM,R/U TO TEST CASING FROM 250 PSI `LOW FOR 5 MINUTES AND 4,000 PSI HIGH FOR 30 MINUTES. -LINE UP AND PURGE SURFACE SYSTEM. -CLOSE UPPER VBR. -PUMP 3 STROKES TO PRESSURE UP TO 250 PSI. -PUMP TOTAL OF 32 STROKES TO PRESSURE UP TO 4,200 PSI. -OBSERVE LEAK FROM GLAND NUT FROM LOCK DOWN SCREW ON TUBING HEAD. *OUTER ANNULUS PRESSURE=0 PSI. *0 BBL FLUID LOSSES FOR PAST 24 HOURS. 6/22/2013 00:00 - 01:30 1.50 CLEAN P RUNCMP TEST 5-1/2"X-7-5/8"CASING ALONG WITH TOP OF 5-1/2'LINER AT 3,990'. -BLEED OFF PRESSURE AND TIGHTEN GLAND NUT AROUND LOCK DOWN SCREW ON TUBING HEAD. -PRESSURE CASING UP TO 4,170 PSI.WITH 3.1 BBLS. -HOLD TEST FOR 30 CHARTED MINUTES. -BLEED OFF AND RECOVER 3 BBLS. -OPEN UPPER VBR. *VERIFY COMPETENCY OF TEST WITH WTL AT 01:25. PJSM,RIG DOWN TEST EQUIPMENT. 01:30 - 02:00 0.50 CLEAN P. RUNCMP PJSM,BLOW DOWN CHOKE AND KILL LINES. -REVIEW DOYON SOP,DRAIN STACK AND BLOW DOWN SURFACE LINES. 02:00 - 06:00 4.00 CLEAN P RUNCMP DRILL OUT CEMENT AND SHOE TRACK OF 5-1/2"TIE BACK STRING WITH 4-3/4"BIT ASSEMBLY. -PJSM ON DRILLING AHEAD. -MAKE UP TOP DRIVE AND OBTAIN PARAMETERS. -OBTAIN SLOW PUMP RATES. -PUW 145K,SOW 143K,ROTW 143K,90 RPM WITH 2K TORQUE OFF,4 BPM WITH 1,800 PSI. -WASH DOWN F/8,468'T/8,536'. -DRILL OUT CEMENT F/8,536'T/DRILL PIPE AND LINER WIPER DARTS AT 8,631'AT 100 RPM WITH 2 TO 5K TORQUE. -LOCATE LANDING COLLAR AT 8,636'AND DRILL THROUGH AT 04:45 WITH NO EXCESS TORQUE RUNNING 5 TO 8K WEIGHT ON BIT. SEND 30 BBL HI-VIS SWEEP PUMPING AT 4 BPM WITH 2,050 PSI.ON BOTTOM AND 4K TORQUE AND DRILL THROUGH CEMENT TO FLOAT COLLAR AT 8,678'TORQUE UP TO 5K, DRILL DOWN TO 8,700'WITH 3K TORQUE, STOP ROTATION AT 8,700'AND WASH DOWN TO 8,710'. -PICK UP 10'AND TAG SOLID AGAIN AT 8,710' Printed 7/8/2013 10:06:11AM • • 4 North America-ALASKA-BPS { r r i n mma Re ort { Ope at o Su ry p 1 r'/nom Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 07:30 1.50 CLEAN P RUNCMP CIRCULATE HOLE CLEAN WHILE RECIPROCATING AND ROTATING DRILL STRING. -PJSM,PUMP 4 BBL PER MINUTE SWEEP WITH 1800 PSI. -ROTATE AT 80 RPM WHILE RECIPROCATING F/8,670'T/8,700'. -SWEEP OUT OF HOLE WITH FINE CEMENT RETURNS AHEAD OF SWEEP. -NO SIGNIFICANT AMOUNT OF METAL CUTTINGS ON DITCH MAGNETS. -FLOW CHECK-WELL STATIC. 07:30 - 08:00 0.50 CLEAN P RUNCMP PJSM,BLOW DOWN TOP DRIVE. -BEAVER SLIDE OPERATIONS. -PICK UP AND BRING IN 2-7/8"HT-PAC THREAD PROTECTORS. 08:00 - 10:00 2.00 CLEAN P RUNCMP PJSM,POOH WITH 4-3/4"CLEAN OUT ASSEMBLY USED FOR CLEANING 5-1/2" LINER. -POOH STANDING BACK 4"DRILL PIPE F/ 8,710'T/5,239'. -MONITOR WELL BEFORE PULLING OUT W/ 2-7/8"PAC DRILL PIPE-WELL STATIC. 10:00 - 10:30 0.50 CLEAN P RUNCMP *KICK DRILL AND AFTER ACTION REVIEW. 10:30 - 11:30 1.d0 CLEAN P ®® RUNCMP PJSM,RIG UP TO LAY DOWN 2-7/8"PAC DRILL PIPE. 11:30 - 12:00 0.50 CLEAN P RUNCMP PJSM,POOH WITH 4-3/4"CLEAN OUT ASSEMBLY USED FOR CLEANING 5-1/2' LINER. -LAY DOWN 2-7/8"PAC DRILL PIPE TO PIPE SHED F/5,239'T/4,766' '0 PSI ONOA. •O BBL FLUID LOSS FROM MIDNIGHT TO NOON. 12:00 - 13:00 1.00 CLEAN P -_ RUNCMP PJSM,GREASE AND SERVICE TOP DRIVE, BLOCKS AND DRAW WORKS. 13:00 - 15:00 2.00 CLEAN P RUNCMP PJSM, POOH WITH 4-3/4"CLEAN OUT ASSEMBLY USED FOR CLEANING 5-1/2' LINER. -LAY DOWN 2-7/8"PAC DRILL PIPE TO PIPE SHED F/4,766'T/2,950'. 15:00 - 15:30 0.50 CLEAN P RUNCMP 'KICK DRILL WITH AFTER ACTION REVIEW, RESPONSE TIME 2 MINUTES AND 50 SECONDS. 'H2S TABLE TOP DRILL. 15:30 - 16:00 0.50 CLEAN N SFAL 2,950.00 RUNCMP REPLACE PIN ON DOUBLE STACK TONGS. 16:00 - 19:00 3.00 CLEAN P RUNCMP POOH WITH 4-3/4"CLEAN OUT ASSEMBLY USED FOR CLEANING 5-1/2"LINER. -LAY DOWN 2-7/8"PAC DRILL PIPE F!2,950' T/ 800'. "KICK DRILL,2 MINUTES AND 50 SECONDS RESPONSE TIME. **COMPLEX DRILL OF FOSV LEAKING OUT OF VALVE BODY WHEN CLOSED AND PIPE IN HOLE HYDRAULIC OUT OF HOLE THROUGH ANNULAR PREVENTER. 19:00 - 19:30 0.50 CLEAN P ■- RUNCMP AFTERACTION N WITH CREW WHAT WENT WELL AND B WHAT COULD BE IMPROVED. Printed 7/8/2013 10.06.11AM • • � �fw�/ p� � '7'n North America-ALASKA Operation Summary Report Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) I Start Date:6/7/2013 End Date:6/28/2013 tX4-0oX8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM I Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth ! Phase I Description of Operations (hr) (usft) 19:30 - 20:00 0.50 CLEAN P RUNCMP I POOH WITH 4-3/4"CLEAN OUT ASSEMBLY USED FOR CLEANING 5-1/2"LINER. PULL OUT OF THE HOLE AND LAY DOWN 2-7/8"PAC PIPE F/224'. 20:00 - 22:30 2.50 CLEAN P RUNCMP 'FLOW CHECK WELL BEFORE PULLING NONSHEARABLES THROUGH BOPE STACK -PJSM,MAKE UP CROSSOVERS FOR SAFETY JOINT AND SAFETY VALVES. -OBTAIN AND DOCUMENT SIZES OF ALL COMPONENTS USED TO ASSEMBLE FLOOR VALVE AND SAFETY JOINT. *DISCUSSED WITH CREW THE IMPORTANCE I OF USING A SAFETY JOINT THAT CAN BE PICKED UP WITH SAME ELEVATORS THAT ARE CURRENTLY BEING USED TO PULL NONSHEARABLES AND TO HAVE THE CAPABILITIES OF MAKING UP SAFETY JOINT TO FLOOR VALVE AND TO HAVE THE I CORRECT CROSSOVERS TO PLACE ON TOP OF SAFETY JOINT ONCE INSTALLED TO ACCEPT DART VALVE AND BE READY TO I STRIP IN HOLE WITH WORK STRING OF 4" XT39. 22:30 - 23:00 0.50 CLEAN P RUNCMP PJSM,LAY DOWN 5-1/2"CLEAN OUT BHA. -LAY DOWN 3-1/8"PAC DRILL COLLARS. I-BREAK OUT AND LAY DOWN JARS,BIT SUB I AND BHT STX-1 4-3/4"BIT. 23:00 - 00:00 1.00 CLEAN P RUNCMP PJSM,BREAK DOWN CROSSOVERS ON 2-7/8" SAFETY JOINT AND SAFETY VALVES. -CLEAN AND CLEAR RIG FLOOR OF ALL 'TOOLS AND EQUIPMENT NOT NEEDED FOR UPCOMING E-LINE OPERATION. *0 BBL FLUID LOSS FOR PAST 24 HOURS. I*OUTER ANNULUS PRESSURE=0 PSI. 6/23/2013 00:00 - 02:00 2.00 CLEAN P RUNCMP PJSM-SPOT AND R/U SLB E-LINE FOR DRIFTING TAIL PIPE OF"ZXP"PACKER AT 8,690'. -PICK UP SCHLUMBERGER TOOLS AND EQUIPMENT THROUGH BEAVER SLIDE. 02:00 - 04:30 2.50 CLEAN P RUNCMP RIH WITH E-LINE TOOL STRING. -MAKE UP TOOL STRING WITH 2.75"JUNK BASKET ON BOTTOM WITH CCL AT 14'ABOVE JUNK BASKET. -RIH WITH E-LINE ASSEMBLY AT 250 FEET PER MINUTE LOGGING DOWN AND TAG AT 8,710. -POOH WITH E-LINE T/8,550',RIH AND CONFIRM TAG AT 8,710'. -POOH F/8,710'T/SURFACE WITH E-LINE, DOWNLOAD AND PRINT LOG. 04:30 - 05:00 0.50 CLEAN P RUNCMP I DISCUSS PLAN FORWARD WITH ODE. *CALL TOWN ODE AND CONFIRM PLAN FORWARD OF RUNNING IN HOLE WITH 3-1/4" ID RCJB. 05:00 - 05:30 0.50 CLEAN P RUNCMP RIG DOWN SCHLUMBERGER E-LINE. -PJSM ON BEAVER SLIDE OPERATIONS AND BREAKING DOWN E-LINE TOOL STRING. -REMOVE E-LINE EQUIPMENT FROM RIG FLOOR THROUGH BEAVER SLIDE. Printed 7/8/2013 10:06:11AM • • • Operation Summary Re. Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:617/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 j Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs ' Task Code !I NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 07:00 1.50 CLEAN P RUNCMP PJSM,MAKE UP SAFETY JOINT FOR NON-SHEARABLE 3-1/8"DRILL COLLARS IN STACK. -ASSEMBLE AND TORQUE SAFETY JOINT AND FLOOR VALVE. 07:00 - 09:00 2.00 CLEAN P RUNCMP PJSM,PICK UP 4-3/4"REVERSE CIRCULATING ■- JUNK BASKET BHA. -BEAVER SLIDE OPERATIONS. 09:00 - 09:30 ! 0.50 CLEAN N RREP RUNCMP PJSM,INSPECT TOP DRIVE FOR LEAK -LOTO TOP DRIVE. I-PULL INSPECTION PLATE AND CHECK FOR LEAKS ON HYDRAULIC PUMP. -TIGHTEN HYDRAULIC COUPLING. 1-RE-INSTALL PLATE,UNLOCK AND TEST. I TESTED GOOD WITH NO LEAKS. 09:30 - 10:00 0.50 CLEAN P RUNCMP PICK UP 4-3/4"REVERSE CIRCULATING JUNK BASKET BHA. -MAKE UP 3-1/8"JAR WITH TWO 3-1/8"BOOT BASKETS AND 4-3/4"RCJB WITH 3-1/4"X 3' BASKET. 1-SET IN HOLE AT 60' 10:00 - 10:30 0.50 CLEAN P RUNCMP ,*KICK DRILL,RESPONSE TIME-1 MINUTE AND -- 15 SECONDS. -AFTER ACTION REVIEW ON WHAT WENT WELLAND WHAT COULD BE IMPROVED. 10:30 - 11:30 1.00 GLEAN P RUNCMP PICK UP 4-3/4"REVERSE CIRCULATING JUNK BASKET BHA. -MAKE UP 3-1/8"DRILL COLLARS AND RIH T/ 209'. 11:30 - 12:00 0.50 CLEAN P RUNCMP PJSM,CHANGE OUT ELEVATORS FROM 3-1/2" BOTTLENECK TO 2-7/8"YT. *0 BBL FLUID LOSS FROM MIDNIGHT TO NOON. *OUTER ANNULUS PRESSURE=0 PSI. 12:00 - 18:00 6.00 CLEAN P RUNCMP RIH WITH 4-3/4"REVERSE CIRCULATING JUNK BASKET DRESSED WITH 3-1/4"X 3' BASKET. -PJSM,PICK UP AND RUN IN THE HOLE WITH 2-7/8"HT-PAC DRILL PIPE F/230'T/5,048' FROM PIPE SHED. 18:00 20:30 2.50 CLEAN P RUNCMP RIH WITH 4-3/4"REVERSE CIRCULATING JUNK BASKET DRESSED WITH 3-1/4"X 3' BASKET. -CHANGE OUT ELEVATORS FROM 2-7/8"YT TO 4"DRILL PIPE. -RIH WITH 4"DRILL PIPE FROM DERRICK F/ 5,048'T/8,658'. -MAKE UP TOP DRIVE AND OBTAIN PARAMETERS. -PUW 156K,SOW 139K. -RIH SLOWLY AND TAG UP AT 8,699'. -SET 4K DOWN ON OBSTRUCTION. -PICK STRING UP TO 8,658'WITH OVERPULL OF 2K OVER AT 8,699'. Printed 7/8/2013 10:06:11AM • • }' North America-ALASKA BP %Ope rayi on S ummary Kepol. Common Well Name.02-27 AFE No Event Type:WORKOVER(\NO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud DateTme:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 21:30 1.00 CLEAN P RUNCMP DROP 9/16"DIVERTER BALL,WASH AND VACUUM DEBRIS FROM WELLBORE WITH RCJB. -BREAK OUT STAND OF DRILL PIPE AND DROP BALL. -PUMP BALL ON SEAT AT 3 BPM WITH 1400 PSI. -PUW 156K,SO 139K,ROTW 146K. -60 RPM TORQUE WITH 1-2K. -AFTER 33 BBLS PUMPED PRESSURE INCREASED TO 1520 PSI. -PUMP 65 BBLS.TO ENSURE SOLID COLUMN OF FLUID IN DRILL PIPE. -BRING PUMPS UP TO 3.7 BPM WITH 2100 PSI. -WASH DOWN ROTATING AT 60 RPM WITH 3-4K TORQUE WHEN TAGGING AT 8,699'. -WASH AND ROTATE DOWN F/8,699'T/8,713' WITH 1-4K WOB. -CLEANS UP QUICKLY,PICK UP 40'AND REPEAT STEPS TWO MORE TIMES WITH NO WOB AND EXCESS TORQUE TO ENSURE `HOLE IS CLEAN. -PICK UP 40'SHUT DOWN PUMPS AND ROTATION AND DRY TAG AT 8,713',PICK UP 40'AND DRY TAG ONCE MORE WITH SAME RESULTS. -FLOW CHECK-WELL STATIC. 21:30 - 23:00 1.50 CLEAN`- P RUNCMP POOH WITH 4-3/4"REVERSE CIRCULATING JUNK BASKET DRESSED WITH 3-1/4"X 3' BASKET. -PJSM,BLOW DOWN TOP DRIVE AND POOH F/8,670'T/7,500'STANDING BACK 4"DRILL PIPE. `KICK DRILL,RESPONSE TIME-1 MINUTE AND 50 SECONDS. *AAR MEETING ON WHAT WENT WELL AND WHAT COULD BE IMPROVED. 23:00 - 00:00 1.00 CLEAN P RUNCMP POOH WITH 4-3/4"REVERSE CIRCULATING JUNK BASKET DRESSED WITH 3-1/4"X 3' BASKET. -STAND BACK 4"DRILL PIPE F/7,500'T/5,048'. PJSM,SWAP TO 2-7/8"ELEVATORS. -MAKE UP CROSSOVERS FOR FLOOR SAFETY VALVE. 'O BBL FLUID LOSS FOR PAST 24 HOURS. 'OUTER ANNULUS PRESSURE=0 PSI. 6/24/2013 00:00 - 05:00 5.00 CLEAN P RUNCMP POOH WITH 4-3/4"REVERSE CIRCULATING JUNK BASKET DRESSED WITH 3-1/4"X 3' BASKET. -L/D 2-7/8"HT-PAC DRILL PIPE IN PIPE SHED F/5,048'T/233'. Printed 7/8/2013 10:06:11AM • orth America-ALASKA-BPS Operation Summary Report Common Well Name:02-27 AFE No Event Type:WORKOVER(VVO) Start Date:6/7/2013 End Date:6/28/2013 X4-OOX8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud DateTme:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 06:00 1.00 CLEAN P RUNCMP POOH WITH 43/4"REVERSE CIRCULATING JUNK BASKET BHA. -FLOW CHECK-WELL STATIC. -ASSEMBLE PROPER SAFETY JOINT FOR PULLING NON-SHEARABLES ACROSS BOPE STACK. -POOH AND LAY DOWN LAST JOINT OF 2-7/8" HT-PAC DRILL PIPE. -POOH LAYING DOWN 3-1/8"DRILL COLLARS. ONE CUP OF SMALL METAL PIECES RECOVERED IN.JUNK BASKET. **ALSO ONE CUP OF LARGE CEMENT CHUNKS AND SMALL METAL PIECES RECOVERED FROM BOOT BASKETS. 06:00 - 07:00 1.00 CLEAN P RUNCMP PJSM,REMOVE BAKER TOOLS FROM RIG FLOOR THROUGH BEAVER SLIDE. 07:00 - 08:00 1.00 CLEAN P RUNCMP PJSM,WITH SLB SLICK LINE AND DDI CREW ® ON RN SLICK LINE UNIT AND TOOLS. I-BEAVER SLIDE OPERATIONS. 08:00 - 10:00 2.00 CLEAN P RUNCMP RIH WITH SLICK LINE BHAASSEMBLY TO DETERMINE IF 5-1/2"X 3-1/2"CROSSOVER AT 8,713'CLEAR OF ANY OBSTRUCTION. /ASSEMBLE SLICK LINE BHA WITH 2.7" MAGNET TO DRIFT INSIDE OF 3-1/2"TUBING. -RIH WITH SLICK LINE. 10:00 - 10:30 0.50 CLEAN P RUNCMP KICK DRILL WITH SLICK LINE IN HOLE. *AAR W/CREW ON WHAT WENT WELL AND WHAT COULD BE IMPROVED. 10:30 - 12:00 1.50 CLEAN P RUNCMP RIH WITH SLB SLICK LINE 2.7"MAGNET BHA AT 200'PER MINUTE. -TAG UP AT 8,721'. *0 BBL LOSSES FROM MIDNIGHT TO NOON. 12:00 - 13:00 1.00 CLEAN P - ®_ RUNCMP POOH WITH 2.7"MAGNET BHA ON SLICK LINE AT 200'PER MINUTE. 13:00 - 15:30 2.50 CLEAN P RUNCMP PJSM,RIG DOWN SLB SLICK LINE. -BEAVER SLIDE OPERATIONS. -CLEAN AND CLEAR SLICK LINE TOOLS FROM RIG FLOOR. 15:30 - 17:00 1.50 CLEAN P ■- RUNCMP PJSM,RIH WITH 4"DRILL PIPE FROM DERRICK. -MAKE UP STACK WASHER AND RIH T/3,894'. 17:00 - 17:30 0.50 CLEAN P RUNCMP PJSM,SLIP AND CUT 59.5'DRILL LINE. 17:30 - 18:30 1.00 CLEAN P RUNCMP RIG EVACUATION,ALL HANDS RESPONDED TO MUSTER AREA. *AAR HELD WITH CREW ON WHAT WENT WELLAND WHAT COULD BE IMPROVED. 18:30 - 20:00 1.50 CLEAN P RUNCMP PJSM,SLIP AND CUT 59.5'OF DRILL LINE. ■- -INSPECT AND SERVICE TOP DRIVE,BLOCKS, AND AND DRAW WORKS. 20:00 - 23:00 3.00 CLEAN P RUNCMP POOH LAYING DOWN 4"DRILL PIPE INTO PIPE SHED F/3,894'. PJSM AND REVIEW SOP OF LAYING DOWN DRILL PIPE. 23:00 - 23:30 0.50 BOPSUR P RUNCMP PJSM,FLUSH BOP STACK AT 16 BBLS PER MINUTE WITH 120 PSI.WHILE ROTATING AT 100 RPM. -LAY DOWN SINGLE OF 4"DRILL PIPE AND STACK WASHER. *A LITTLE METAL SEEN IN RETURNS CAPTURED WITH DITCH MAGNETS. Printed 7/8/2013 10:06.11AM • • ©rm America-ALASKA BP • . Operation Summary Report; mss, Common Well Name:02-27 1 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) L Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud DateTme:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. U I: Active datum:02-27©60.65usft(above Mean Sea Level) Date ! From-To Hrs Task Code NPT NPT Depth Phase Description of Operations ' (hr) (usft) 23:30 - 00:00 0.50 BOPSUR P RUNCMP PJSM ON PULLING WEAR BUSHING. -DRAIN BOPE STACK -PULL WEAR BUSHING. 6/25/2013 00:00 - 02:30 2.50 BOPSUR P RUNCMP PJSM,RIG UP FOR WEEKLY BOPE TEST. -MAKE UP TWO 4"FOSV WITH 4"DART VALVE. -SET TEST PLUG AND RIG UP TEST EQUIPMENT. 02:30 - 09:00 6.50 BOPSUR P RUNCMP 'PJSM,TEST BOPE W/3-1/2"TEST JOINT. -TEST 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH *AOGCC BOB NOBLE WITNESS TEST. *NO FAILURES. `ALL TEST CHARTED,SEE ATTACHED TEST CHARTS. 09:00 - 10:00 1.00 BOPSUR P RUNCMP PJSM,R/D BOPE TEST EQUIP. 10:00 - 11:00 1.00 BOPSUR P RUNCMP PJSM,CLEAN AND CLEAR RIG FLOOR OF ALL TOOLS AND EQUIP NOT NEEDED FOR 'UPCOMING JOB. BEAVER SLIDE OPERATIONS. 11:00 - 15:00 4.00 RUNCOM P RUNCMP PJSM,MOBILIZE TUBING EQUIPMENT FOR RUNNING 3-1/2"COMPLETION. '-REMOVE SHORT BAILS. -INSTALL COMPENSATOR AND LONG BAILS. *0 BBL FLUID LOSS FROM MIDNIGHT TO NOON. MOBILIZE AND RIG UP DOUBLE STACK TONGS TO RIG FLOOR. 15:00 16:00 1.00 RUNCOM N RREP I RUNCMP PJSM,TROUBLE SHOOT ELECTRICAL ISSUE WITH STABBING BOARD WINCH. -RIG ELECTRICIAN REPAIR AND INSTALL WINCH FOR STABBING BOARD FOR COMPENSATOR. 16:00 - 16:30 0.50 RUNCOM P RUNCMP PJSM W/CSG HAND AND RIG CREW ON RIH W/3-1/2"13 CR-85 VAM TOP 9.2# I COMPLETION. 16:30 - 17:30 1.00 RUNCOM P RUNCMP MAKE UP 3.5"WLEG,XN NIPPLE,BAKER 5.5"X3.5"SABL-3 PACKER AND GLM. -RIH T/973'. *ALL CONNECTIONS BAKER LOC'D BELOW PACKER AND MADE UP TO 2900 FT/LBS. *DRIFTED BAKER 5.5"X3.5"SABL-3 PACKER WITH BALL AND ROD FOR CLEARANCE. 17:30 - 18:30 1.00 RUNCOM P RUNCMP I KICK WHILE TRIPPING DRILL. -AAR W/RIG CREW ON WHAT WENT WELL AND WHAT COULD BE IMPROVED. *WELL SHUT IN USING ANNULAR PREVENTER IN 2 MINUTES 36 SECONDS. *DRILL COMPLICATION-ANNULAR DETERMINED TO BE LEAKING-SHUT IN UPPER PIPE RAMS. 18:30 - 00:00 5.50 RUNCOM P RUNCMP PJSM W/CSG HAND AND RIG CREW ON RIH W/3-1/2"13 CR-85 VAM TOP 9.2# COMPLETION. -RIH F/973'T/3,150'. *ALL CONNECTIONS DOPED WITH JET LUBE SEAL GUARD AND MADE UP TO 2900 FT/LBS. Printed 7/8/2013 10:06:11AM • • ( North America-ALASKA Operation Summary Report; Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase ■ Description of Operations (hr) (usft) 6/26/2013 00:00 - 02:30 2.50 RUNCOM P RUNCMP PJSM W/CSG HAND AND RIG CREW ON RIH W/3-1/2"13 CR-85 VAM TOP 9.2# COMPLETION. -RIH F/3,150'T/3286'. *UD JOINT 99(31.38'),P/U JOINT 300(31.49'), CHANGE OUT COLLAR ON JOINT 98. ALL CONNECTIONS DOPED WITH JET LUBE SEAL GUARD AND MADE UP TO 2900 FT/LBS. 02:30 - 03:00 0.50 RUNCOM P RUNCMP SIT DOWN 5K AT 3995'(5.5"LINER TOP AT 1 3990'). -MAKE 2 MORE ATTEMPTS WITH THE SAME RESULT. 1-TURN STRING 1 TURN TO THE LEFT. -WORK STRING AND SET DOWN AGAIN AT 3995'. -TURN STRING 1/2 TURN TO THE LEFT AND WENT THROUGH 5.5"3995'WITH WLEG. 03:00 RUNCMP RIH W/3-1/2"13 CR-85 VAM TOP 9.2# - 05:00 2.00 RUNCOM P � COMPLETION. -RH F/3995'T/5350'. *ALL CONNECTIONS DOPED WITH JET LUBE SEAL GUARD AND MADE UP TO 2900 FT/LBS. 05:00 - 05:30 0.50 RUNCOM P RUNCMP KICK WHILE TRIPPING DRILL. -AAR WI RIG CREW ON WHAT WENT WELL AND WHAT COULD BE IMPROVED. WELL SHUT IN USING ANNULAR PREVENTER IN 1 MINUTE 46 SECONDS. 05:30 - 08:30 3.00 RUNCOM P RUNCMP j RIH W/3-1/2"13 CR-85 VAM TOP 9.2# COMPLETION. -RIH F/5,350'T/6,863'. I*ALL CONNECTIONS DOPED WITH JET LUBE SEAL GUARD AND MADE UP TO 2900 FT/LBS. 08:30 - 09:30 1.00 RUNCOM P_ RUNCMP RIH W/3-1/2"13 CR-85 VAM TOP 9.2# COMPLETION. -RIH F/6,863'T/7,335'. *ALL CONNECTIONS DOPED WITH JET LUBE SEAL GUARD AND MADE UP TO 2900 FT/LBS. *SIM OPS-R/U CELLAR TO REV.CIRCULATE AND PRESSURE TEST TUBING. 09:30 - 11:30 2.00 RUNCOM N RREP 7,335.00 RUNCMP PJSM,TROUBLE SHOOT PIPE SKATE IN PIPE SHED. -RESTRING COUNTER BALANCE ON PIPE SKATE. 11:30 - 12:00 0.50 RUNCOM P RUNCMP I RIH W/3-1/2"13 CR-85 VAM TOP 9.2# COMPLETION. -RIH F/7,335'T/7,587'. ALL CONNECTIONS DOPED WITH JET LUBE SEAL GUARD AND MADE UP TO 2900 FT/LBS. *0 BBL FLUID LOSS FROM MIDNIGHT TO NOON. 12:00 - 14:00 2.00 RUNCOM P RUNCMP RIH W/3-1/2"13 CR-85 VAM TOP 9.2# COMPLETION. -RIH F/7,587'T/8,500" *ALL CONNECTIONS DOPED WITH JET LUBE SEAL GUARD AND MADE UP TO 2900 FT/LBS. 14:00 - 14:30 0.50 RUNCOM P RUNCMP *KICK WHILE TRIPPING DRILL,RESPONSE I TIME 1 MINUTE AND 50 SECONDS. -AAR HELD WITH DDI CREW ON WHAT WENT WELLAND WHAT COULD BE IMPROVED. Printed 7/8/2013 10:06:11AM • • • /33vim North America-ALASKA Bl %' Operation Summary Repo Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X400X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 15:00 0.50 RUNCOM P RUNCMP IR W/3-1/2"13 CR-85 VAM TOP 9.2# COMPLETION. -RIH F/8,500'T18,664". *ALL CONNECTIONS DOPED WITH JET LUBE SEAL GUARD AND MADE UP TO 2900 FT/LBS. 15:00 - 16:00 1.00 RUNCOM P RUNCMP PJSM,LAND FMC TC-1A-EMS TUBING I HANGER W/4.5"TCII THREADS TOP AND BOTTOM. -REMOVE AIR SLIPS AND STRIPPING RUBBER. -PICK UP LANDING JOINT AND LAND. -FMC SERVICE REP VERIFY HANGER LANDED. -RUN IN LOCK DOWN SCREWS. *LANDED AT 8,670.28'. I*FINAL PUW 122K. *FINAL SOW 118K 16:00 - 19:30 3.50 RUNCOM P RUNCMP I PJSM,DISPLACE WELL WITH 120 DEGREE 9.8 PPG BRINE W/CORROSION INHIBITOR. -PUMP 300 BBLS W/550 PSI AT 2 BPM. 19:30 - 22:30 3.00 RUNCOM P RUNCMP PJSM,SET AND TEST 5.5"X 3.5"BAKER SABL PACKER AND 3-1/2"13 CR-85 VAM TOP 9.2# . COMPLETION. -DROP BALL AND ROD. -RIG UP TEST PUMP. -FILL CHOKE AND KILL LINES. -PUMP 2 BBLS 9.8 PPG BRINE DOWN TUBING, PSI CAME UP TO 800 PSI AND SHUT IN MUD PUMP. -LINE UP ON TEST PUMP AND PRESSURE UP TUBING TO 4500 PSI. 1-HOLD 4500 PSI FOR 15 MINUTES TO SET PACKER. -BLEED OFF TUBING PRESSURE TO 3120 PSI FOR 30 MINUTES AND CHART. -BLEED OFF TUBING PRESSURE TO 1500 PSI AND SHUT IN. -PRESSURE UP IA TO 3200 PSI FOR 45 MINUTES AND CHART. *NOT ABLE TO REACH BP WTL,EMAIL RESULTS OF TEST TO BP RWO OPERATIONS SUPERINTENDENT GREG SARBER AND DISCUSS RESULTS.GIVEN PERMISSION TO PROCEED WITH OPERATIONS. 22:30 - 23:00 0.50 RUNCOM P RUNCMP PJSM,SHEAR DCR VALVE. -BLEED OFF TUBING,SHEAR DCR VALVE AS TUBING PRESSURE DROPS PAST 400 PSI. -PUMP 5 BBLS DOWN IA W/9.8 PPG BRINE AT 2 BPM AT 250 PSI TO VERIFY DCR SHEAR. -PUMP 5 BBLS DOWN TUBING W/9.8 PPG BRINE AT 2 BPM W/200 PSI TO VERIFY DCR SHEAR. 23:00 - 00:00 1.00 WHSUR P WHDTRE PJSM,INSTALL TWO WAY CHECK AND TEST. -INSTALL TWC WITH DRY ROD. -TEST TWC TO 1000 PSI FROM BELOW FOR 10 CHARTED MINUTES. 6/27/2013 00:00 - 01:00 1.00 WHSUR P WHDTRE TEST TWC FROM ABOVE TO 3500 PSI FOR 10 CHARTED MINUTES. 01:00 - 02:00 1.00 BOPSUR P WHDTRE PJSM,REMOVE FLUIDS FROM BOPS AND — BLOW DOWN CHOKE AND KILL LINES. Printed 7/8/2013 10:06:11AM • • • North America-ALASKA-BP -Operation Summary Report Common Well Name:02-27 AFE No Event Type:WORKOVER(WO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. UW: Active datum:02-27©60.65usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 09:00 7.00 BOPSUR P WHDTRE PJSM,INSPECT BOPS. -REMOVE MOUSEHOLE. -OPEN RAM DOORS ON BOPS AND INSPECT BOP RAMS. -CLEAN OUT CEMENT FROM CAVITIES AND INSPECT SEALS. 09:00 - 10:00 1.00 BOPSUR P WHDTRE PJSM,NIPPLE DOWN BOPE 10:00 - 11:30 1.50 BOPSUR P WHDTRE SAFETY MEETING WITH BP RWO ■ OPERATIONS SUPERINTENDENT ON BP SAFETY EXPECTATIONS. 11:30 - 12:00 0.50 BOPSUR P WHDTRE PJSM,NIPPLE DOWN BOPE. 12:00 - 12:30 0.50 BOPSUR P ■ WHDTRE SAFETY MEETING WITH BP RWO OPERATIONS SUPERINTENDENT ON BP SAFETY EXPECTATIONS. 12:30 - 13:00 0.50 BOPSUR P WHDTRE PJSM,NIPPLE DOWN BOPE 13:00 - 14:30 1.50 BOPSUR P ® WHDTRE NIPPLE DOWN BOPE. -STAND BACK BOPE STACK IN CELLAR AND SECURE. 14:30 - 15:30 1.00 WHSUR P ® WHDTRE PJSM,NIPPLE UP 11"X 4 1/16"5K ADAPTER FLANGE 15:30 - 17:00 1.50 WHSUR P WHDTRE PJSM;PRESSURE TEST HANGER VOID 250 PSI LOW FOR 5 MINUTES AND 5000 PSI HIGH FOR 30 MINUTES-BOTH TEST GOOD. 17:00 - 18:30 1.50 WHSUR P ® WHDTRE PJSM,PICKUP AND INSTALL FMC 41/16" TREE. 18:30 - 20:00 1.50 WHSUR P WHDTRE PJSM,RIG UP TO PRESSURE TEST TREE. -PRESSURE TEST TREE TO 5000 PSI FOR CHARTED 30 MINUTES:GOOD TEST. 20:00 - 21:30 1.50 WHSUR P WHDTRE PJSM, RIG UP TO U-TUBE IAAND TUBING. 21:30 - 00:00 2.50 WHSUR P WHDTRE PJSM,W/DSM ON TESTING LUBRICATOR. -REVIEW DSM SOP TO TEST LUBRICATOR. -RIG UP LUBRICATOR -TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH. 6/28/2013 00:00 - 00:30 0.50 WHSUR P ._ WHDTRE PJSM,PULL TWC -R/D LUBRICATOR 00:30 - 04:00 3.50 CONDHL P OTHCMP FREEZE PROTECT TUBING X IA. -PJSM,W/LRS AND DDI CREW ON FREEZE PROTECT. -REVIEW LRS SOP W/DDI CREW. -SPOT AND RIG UP LRS. -P/T LINES TO 3500 PSI FOR 5 CHARTED MINUTES. -REVERSE CIRCULATE 100 BBLS DIESEL AT 2 BBL PER MINUTE DOWN IA. -U-TUBE DIESEL TO EQUALIZE TUBING BY IA. -FREEZE PROTECT TO 2325' *ICP AT 2 BPM=300PSI/FCP AT 2 BPM=700PSI 04:00 - 06:30 2.50 WHSUR P WHDTRE PJSM,SET BPV. -REVIEW SOP WITH DSM -RIG UP LUBRICATOR. -TEST LUBRICATOR TO 250 PSI LOW/3000 PSI HIGH FOR FOR 5 CHARTED MINUTES EACH. -SET BPV. -TEST BPV FROM BELOW TO 1000 PSI WITH LRS FOR 10 CHARTED MINUTES WITH DIESEL. Printed 7/8/2013 10:06.11AM • • • North America-ALASKA-BP i , Operation Summary Report Common Well Name:02-27 AFE No Event Type:WORKOVER(\NO) Start Date:6/7/2013 End Date:6/28/2013 X4-00X8D-E:(3,200,000.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:DOYON 14 Spud Date/Time:12/18/1989 12:00:00AM Rig Release:6/28/2013 Rig Contractor:DOYON DRILLING INC. _ UWI: Active datum:02-27 @60.65usft(above Mean Sea Level) Data From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 10:00 3.50 WHSUR P WHDTRE SECURE TREE,CLEAN CELLAR. -TUBING PRESSURE=0 PSI,IA PRESSURE=0 PSI. 10:00 - 12:00 2.00 WHSUR P WHDTRE RIG DOWN RIG FLOOR. -PREP RIG FLOOR TO SKID TO MOVE POSITION. -C/O SAVER SUB AND LOWER IBOP ON TOP DRIVE. *RIG RELEASED AT 12:00 NOON 6-28-13. Printed 7/8/2013 10:06:11AM • • 02-27A, Well History (Post Rig Workover) Date Summary 07/18/13 CTU 8 w/1.75"CT, Scope; Mill Composite Plug. Rig up. Function test BOP's. RIH w/BHA;2.13" ctc,dfcv,jar,disco, circ sub,2.125"venturi(oal=17.42).Tagged top of junk/sand at 8740'.Pooh. Recovered sample of mud/cement. MU BHA#2;2.13"ctc,dfcv,jar, disco,circ sub,crossover,two 2" stingers, crossover,JSN (oal= 19.37')Clean out with gel sweeps from 8746 to 8788. stack 2-5k dw wt on plug. pump two 15 bbl sweeps off top of plug and chase to surface at 80%. MU w/BHA;2.13"ctc,dfcv, jar,disco,circ sub,2.13"Extreme motor 2.13", 5 Bladed Junk mill 2.62"(oal=19.94'). Start milling CBP at 8785'. 07/19/13 CTU 8 w/1.75"CT, Scope; Mill Composite Plug. MU w/BHA; 2.13"ctc,dfcv,jar,disco,circ sub, 2.13" Extreme motor 2.13", 5 Bladed Junk mill 2.62"(oal=19.94'). Continue milling CBP at 8785' Kept stalling, POOH check mill. recovered small pieces of metal in water courses of mill. MU and RIH w/BHA;2.13" ctc,dfcv,jar,disco,circ sub, motor,venturi w/2.3"burnshoe(oal=22.8'). Mill plug at 8788-8791 with minimal stalls. Dry drift and tag CIBP at 9878. pooh. freeze protect with 22 bbls of 50/50 meth. Page 1 of 1 _et TREE= FIVC GEN 4 III sit NOTES: WELL ANGLE `VV13..LFEAD= FMC 02—27A — -CHROM CHROME TBG* ACTUATOR=.'--- AXB_SON 14111L KB.ELEV 63' ...------ji 20"CONDUCTOR, 1--- —110 I 2200' I--I 3-1/2"I-ES X NP,ID=2.813" KOP... 3931' • I [ h/bx Angle= 95-a 1 1539. 91.5#,H940, Datum MD= 9941; D=19.124" GAS LIFT MAICRELS Dett7a1-TVD=--- 88017 SS ST MD IVO car POE VLV LATCH FORT DATE 10-3/4"CSG,45.5#,J-55 BTC,ID=9953" H 3372' 4 3800 3799 7 MMG DOME RK 16 07/08/13 3 6085 5804 36 KBG2 SO t,1T 20 07/08/13 i 2 7524 6993 33 KBG2 OW WT 0 06/26/13 7-5/8"X 5-1/2"BKR ZXP LTP —I 3990' I ........ I i .7.4 ,/TIEBK SIN,D= 4.800" kil 4 1 8524 7821 34 KBG2 DMY vir 0 06/26/13 10-4 k.1 % [7-5/8"X 5-1/2"FLEX OCK LNR HGR,D=4.800" —I 4010' V 4 41 IP i % IP... lel I 1 i? 8687 J-13-1/2"HES X NP,D=2.813" 7-5/8"CSG,29.7#,L-80 ABM BTC — 408' , 46.1 1114 e 4,.., 8620' 45-1/2"X 3-1/2"BKR S-3 R<R,El=2.78* I i XO TO 1-80 BTC V r4 4/P■ a !. 1 6.1 F.Zi 8689" I-13-1/2"FES XN NF),0=2.635" Minimum ID =2.635" @ 8687' ,,, va *...4 64* el 3-112" H ,ES XN NIPPLE ;fri . 0 i '41 I ill I.Al• 8683' H7-5/8*X 5-1/2'ZXP LTFf LW.HGR 0=4 90" 5-1/2"SCAB LW,17#,L-80 TC8. H 8696' li i % ' 8701' H8-1/2"MEG,13=2.992" I •0238 bpf,13=4.892" —I ELMO TT NOT LOGGED TOP OF 3-1/2"LNR I--I 8683' 8706' H 5-1/2"X 3-1/2"XO,0=2.97" 3-1/2"TBG,9.2#,13CR-85 VAM TOP, IH 8700' I.0087 bpf,D=2.992" I I TOP OF 5-1/2"LNR H 9012' II. 9012' 7-518"X 5-1/2"TIW LNR HGR& I SETTWG SLV,13=? I 7-5/8"CSG,29.7#,L-80 BTC,I).=.-6675" H 9296' ■ 3-1/2"LNR,8.81#,1-80 STL, 0087 bpf,D=2.992" 1---1 9653' I--- >< 5-1/2"PALLOUT VVIIIICAN(02-27A)9673'-9685' 5-112"LNR,17#,L-80 FL4S,.0238 bpf,0=4.962" H —9673 9878' —FISR 3-112"CBP MUD 8,PUSHED 4,75"WHPSTOCK(10(16/99) I 9673' (07/19/13) I5-1/2"BRIDGE PLUG(10/15/99) 9694' 4), 9900'ELM H3-1/2"WAD CIBP(08/01/09) I --.....-- ) 444 14 PERFORATION SUMMARY NI, , REF LOG:SPERRY SUN IvIkADIGR ON 10/21/99 ANGLE AT TOP PERF:3r©8986' Note:Refer to Ftoduction DB for historical pert data SIZE SPF 14TERJAL Opn/Sqz SHOT SQZ 2" 6 8986-9010 0 08/01/09 2-1/2' 4 11299-11745 C 11/24/99 2-1/2" 4 10860-11170 C 11/24/99 .1k. AlkILIP 2-1/2* 4 10140-10730 C 11/24/99 PBTD I— 11767" way -N. 2-1/2" 6 10090-10115 C 06/27/02 2" 6 10022-10052 C 02/17/06 3-1/2-LW,9.2#,L-80 NSCT,.0087 bpf,D=2.992' H 11860' 1 DATE REV BY CONSAB4TS DATE REV BY COMMENTS PRIA3HOE BAY UNIT 02/21/90 N28E INITIAL COMPLETION 08/05/13 RIVIIJIM PALLED&PUSHED CBP(07(19/13) WELL: 02-27A 10/28/99 N7ES SIDETRACK(02-27A) 08/14/13 SWIM) CHANGED CBP TO FISH PERM'No: 1990930 08/28/13 D-14 RWO API No: 50-029-21994-01 07/01/13 PJC DRLG HO CORRIDDN SEC 36,T11N,R14E,391'FNL&818'AM. 07/03/13 SM PJC FE4AL ODEAPPROVAL 08/05/13 ALMA()GLV CIO(07/08/13) BP Exploration(Alaska) I, • w����I %i's9 THE STATE Alaska Oil and Gas 01 L SK 1 Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue p- p. Anchorage, Alaska 99501 -3572 ALA` V. Main: 907.279.1433 2 013 David Reem Fax: 907.276.7542 SCANNED APR 1 0 t Engineering Team Leader d 3 BP Exploration (Alaska), Inc. I 9 P.O .Box 196612 Anchorage, AK 99519 -6612 - Re: Prudhoe Bay Field, Put River Pool, PBU 02 -27A Sundry Number: 313-142 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. t oerster Chair DATED this r da y of April, 2013. Encl. STATE OF ALASKA 410 ,, ; -� 4 .4•,,.. ,f; , ; ; ALA OIL AND GAS CONSERVATION COMMISSION �'� DC'S `a(3 APPLICATION FOR SUNDRY APPROVAL • ` `.; 20 AAC 25.280 1. Type of Request ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ® Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ® Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 199 -093 , 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 21994 -01 -00 • 7. If perforating: 0 .» 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ` c ' //) PBU 02 -27A Will planned perforations require a Spacing Exception? ❑ Yes ® No 3.2,0. /3 9. Property Designatior 10. Field / Pool(s): ADL 028308 Prudhoe Bay Field / Put River Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11860' - 8983' • 11767' 8978' 9900', 8700' None Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3372' 10 -3/4" 3372' 3371' 3580 2090 Intermediate 9296' 7 -5/8" 9296' 8443' 6890 4790 Production Liner 661' 5 -1/2" 9012' - 9673' 8223' - 8737' 7740 6280 Liner 3177' 3 -1/2" 8683' - 11860' 7953' - 8983' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8986' - 9010' Below CIBP: 10022' - 11745 8202' - 8221' Below CIBP: 8962' - 8977' 3-1/2", 9.3# L -80 8722' Packers and SSSV Type: 7 -5/8" x 3-1/2" Baker S -3 Packer Packers and SSSV 8675' / 7946' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: i ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation July 1, 2013 ' ® Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sean McLaughlin, 564 -4387 Printed Name: David Reem Title: Engineering Team Leader Email: Sean.McLaughlin ©bp.com Signature: ,,Dc./ C d 'LI'L,, Phone: 564 -5743 Date: 3 ) 5 _ ZG %3 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: r 3 4 ❑ Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: o v p f �5 f t 35 12 5 1 Ft®>MS APR 10 '' '' Spacing Exception Required? ❑Yes E No Subsequent Form Required: l APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date: -� Form 1 -4 Revised 10/ 012 Approved application is valid for 12 months from the date of approval Submit In Duplicate \3 ��J� ►r Y L � �I,� /�3 ..�/ 4 ,5"y bp 0 • 0 , Sundry Request for casing repair Well: 02 -27A Date: 03/19/2013 Engineer: Sean McLaughlin MASP: 2690 psi ✓ Well Type: Producer Estimated Start date: July 1 2013 History: 02 -27 was an original Ivishak producer from 1990 that was plugged back and perforated in the Put River . in 2009. . • 9 -14 -12 Caliper Tubing (113 jts < 20 %, 106 jts 20 -40 %, 44 jt's 40 -85 %, 1 jt 85% wall loss) • 11 -10 -12 Set TTP @ 8700' MD. CMIT- T x IA failed (unable to pressure up) • 11 -11 -12 Re -Set TTP @ 8700' MD. CMIT- T x IA failed again. Set DGLV's in all GLV stations • 11 -12 -12 Re- attempt CMIT w/ PX Plug (instead of TTP). Fail w/ 5 bpm @ 1200 psi leak. LDL log shows T x IA @ 5340', 7250' and PC leak @ 6250' MD • 1 -2 -12 FB pumped 155 BBL's down tubing, IA tracked. Injectivity 5 bpm @ 2055 psi. FB then pumped 155 bbls down IA, tubing tracked. Injectivity 5 bpm @ 1797 psi. Scope of Work: Pull 3 -1/2" L -80 completion. Run 5 -1/2" scab liner. Run 3 -1/2" chrome completion. Pre Rig Prep Work: S 1 DGLV, Pull 3 -1/2" PX plug, Set 3 -1/2" composite plug at 8800', Reset 3 -1/2" PX plug. Drift for 3- 1/2" jet cutter. E 3 Jet cut tubing @ 8,669' (2' from bottom of pup above packer). Reference tubing tally 10/27/99. F 4 Circulate well through the cut with sea water and diesel freeze protect. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. ✓ 6 Set BPV in the tubing hanger. O 7 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed RWO Procedure: 1. MIRU Doyon 14. ND tree. NU and test BOPE with four preventers configured top down (annular, 3- 1/2" x 6" VBR's, blind shears, mud cross' and 3 -1/2" x 6" VBR's). Test the VBR's and annular to 3,500 ✓ psi. 2. Pull and lay down tubing to the jet cut. 3. Mill and retrieve the production packer and tail pipe. 4. Scrape 7 -5/8" casing and polish tieback sleeve. 5. Run 7 -5/8" test packer to 6,500' and test the composite plug to 3,000 psi. Pull up hole to 4,500' and test the 7 -5/8 casing to 3,000 psi. 6. Run and cement 5 -1/2 ", 17 #, L -80 scab liner to 4,000'. 7. Change out the inner casing pack -off while WOC. 8. Run in with drillout assembly to the landing collar. Pressure test casing to 3,000 psi. Mill shoe track V and cleanout to the 3 -1/2" x 5 -1/2" crossover at 8,706'. 9. Run new 3.5" 13Cr completion with 5 -1/2" x 3 -1/2" baker SABL -3 packer. MIT -T & MIT -IA to 3000 psi. I. 10. Set a BPV and RDMO. Post ri Work ✓ 1 Pull BPV S 2 Pull ball and Rod, Pull RHC seat, Install dummy GLV's C 3 Mill 3 -1/2" composite plug and push to bottom. II-ZEE FMC GET WELLHEAD = FNIC • TY NOTES: WELL ANGLE< 70° @ 10035'. I ALTUATOR = AXELSON 02-27A ...... KB. ELEV = 5920' BF. D.EV = Max KOP= 3931' Angle = 95° @ 11538' 2189' H3-1/2" X NIP, ID = 2.813" Datum MD = 9841' Datum 8800 SS 10-3/4" CSG, 45.5#, J-55, ID= 9.953" H 3372' GAS LIFT MANDRELS ST IAD T VD DEV TYPE VLV LATCH PORT DATE 1 3791 3790 7 IVIMM DMY RK 0 11/12/12 2 6933 6499 34 IMIVIM DMY RK 0 11/12/12 7-5/8" CSG, 29.7#, L-80 ABM BTC H 4498' 1—X ... .."... 3 8611 7893 34 RUM DMY RK 0 11/12/121 XO TO L-80 BiTC Minimum ID =2813" @ 2189' ' 8675' H7-5/8" X 4-1/2" BKR S-3 FKR, D= 3.875" 3-112" HES X NIPPLE ITOP OF 3-1/T LNR I 8683' I---- ' v 8683' H7-5/8" X 5-1/2" ZXP LITY LM -GR. 0= 4.90' I g .„.... 13-112" PX PLUG (11/11/12) —1 8700'J 8700' H3-1/2" OTIS X IsiP, ID= 2.813* 1 — 8706' 1-15-1/2" X 3-1/T X0, 0 = 2.97* I 3-1/2" TBG, 9.3#, L-80 EUE 8RD, —1 8722' j 8722' -13-1/2'w1 ID= 2.992" .0087 bpf, ID = 2.992" HE 1T NOT LOGGED I I TOP OF 5-1/2" LtstR 1 9012' — = - 7-5/8" CSG, 29.7#, L-80 BTC, ID = 6.875" —I 9296' A ■ 5-1/2" MLLOUT WINDOW (02-27A) 9673'- 9682' 4.75" WEIPSTOCK — 1 9694' 5-1/T TSV —1 9694' 9900' ELM H 3-1/2" WED CUP (08/01i09) AN 411111 PERFORATION SLUVIARY REF LOG: SFERRY SW NIWT_YGR ON 10/21/99 ANGLE AT TOP PERE: 37* @ 8986' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE SQZ 2" 6 8986 - 9010 C 08/01/09 A... Am. 2-1/2" 4 11299- 11745 C 11/24/99 I PBTD 1 11767' qme ■• 2-1/2" 4 10860 - 11170 C 11/24/99 ' 2-1/2" 4 10140 - 10730 C 11/24/99 3-1/2" LNR, 92#, L-80 NSCT, _0087 bpf, D = 2.992' —I 11860' 2-1/2" 6 10090 - 10115 C 06/27/02 2" 6 10022 - 10052 C 02/17/06 . DATE REV BY 1 T1DNINENTS DATE REV BY COMMENTS PRUDHOE BAY min 1990 ORIGINAL COMPLETION 03/26111 PC LNR & 1BG CORRECTIONS VVELL: 02-27A 10/28/99 WES SIDETRACK 11/01/12 MSS/JM) GLV C/O ( 10/29/12) PERMTT No: F 1990930 01/04/10 DAV/PJC GLV CIO 11/15/12 RCT/JNU SET PX PLUG & GLV CIO ( 11/11-12/12 AR No: 50-029-21994-01 08/30/10 RCTIPJC TBG CORRECTONS SEC 36, T11N, R14E, 434.93' FEL & 4869.5' FM_ 12/14/10 CSR/PJC PERE CORRECTIONS (02/17/06) 1 03/25/11 GJF/PJC SET CE3P(08/01/09) BP Exploration (Alaska) _ L ■ ' TREE.7= FMC GE N 4 WELLI FMC • FETY NOTES: WELL ANGLE < 70° @ 10035'. ACTUATOR = AXELSON 02-27A KB ELEV = ^ 59.20' BE ELEl/ _ - - -- KOP = _ 3931' Max Angle = 95° @ 11538' 2189' -- I3 -1/2" X MP, D = 2.813" DatumMD = 9841' Datum _ TVD = 8800' SS Known tubing leaks at 5,340' and 7,250' • 10 -3/4" CSG, 45.5#, J-55, D= 9.953" HI 3372' GAS LFT MANDRELS ST MD T` =3 DEV TYPE VLV LATCH_ PORT DATE t v 1 3791 3790 7 MMM DMY RK 0 11/12/12 X 2 6933 6499 34 MMM DMY RK 0 11/12/12 7 -5/8" CSG, 29.7 #, L -80 ABM BTC H 4498' ^ 3 8611 7893 34 MMM DMY RK 0 11/12/12 XOTOL -80BTC "✓ " PC leak at 6,250' Minimum ID = 2.813" @ 2189' ' _ Jet cut tubing at 8,669' 3-1/2" HES X NIPPLE 8675' H7 -5/8" X4 -1/2" BKRS -3 PKR, D= 3.875" TOP OF 3-1/2" LM I I 8683' I-- 8683' — 17 - 5/8" X 5-1/2" ZXP LTP/ LNIR HGR, ID= 4.90" J 3-1/2' PX PLUG H 8 700' ■ A 8700' H3 OTIS X NIP, ID = - 2.813" I 8706' — I 5 -1/2" X 3-1/2" X0, 13= 2.97" I 3-1/2" TBG, 9.3#, L -80 EUE8RD, H 8722' I-- 8722' JH3 -1/2" WLEG, ID= 2.992" 0087 bpf, D= 2.992" H I E MD TT NOT LOGGED 3 -1/2" Composite plug set at 8,800' 1 '' I I Top of Put river perfs at 8986' TOP OF 5-1/2" LNR H 9012' _ 7 7 -5/8" CSG, 29.7 #, L -80 BTC, ID= 6.875" —1 9296' a k 5-1/2" MILLOUT WNDOW (02 - 27A) 9673' - 9682' 4.75" WI-W TOCK -1 9694' 5-1/2" F —i 9694' / 9900' ELM H3 -1/2" WFD CEP (08 /01/09) PERFORATION SUMMARY REF LOG: SPERRI' SUN MVVLYGR ON 10/21/99 ANGLE AT TOP PERF: 37° @ 8986' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE SQZ 2" 6 8986 - 9010 C 08/01/09 . = =. 2-1/7 4 11299 - 11745 C 11/24/99 FBTD H 11767' %\.' 2 -1/2" 4 10860 - 11170 C 11/24/99 2-1/7 4 10140 - 10730 C 11/24/99 3-1/2" LNR, 9.2#, L -80 NSCT, .0087 bpf, 13= 2.992" —I 11860' 2-1/7 6 10090 - 10115 C 06/27/02 2" 6 10022 - 10052 C 02/17/06 DATE REV BY COMMIENTS DATE REV BY COM ENTS PRLAHOE BAY MIT 1990 ORIGINAL COMPLETION 03/26/11 PJC LNR & TBG CORRECTIONS WELL 02 -27A 10/28/99 N7ES SIDETRACK 11/01/12 MSS/JMD GLV C/O (10/29/12) FERMI No: '1990930 01/04/10 DAV /PJC GLV C!O 11/15/12 RCT /JMD SET PX PLUG & GLV C/O (11/11 -12/12 API No: 50- 029 - 21994-01 08/30/10 RCT /PJC TBG CORRECTIONS SEC 36, T11 N, R14E, 434.93' FEL & 4869.5' FM_ 12/14/10 CSR/PJC PERF CORRECTIONS (02/17/06) 03/25/11 GJF /PJC SET CBP (08/01 /09) BP Exploration (Alaska) TREE P. FMC G9V 4 • .FETY NOTES: WELL ANGLE < 70° @ 10035'. I I" '= 02 27A .' ACTUATOR = AXELSON � KB- ELEV = 59.20' BF. ELEV = Proposed - - KOP = 3931' Max Angle = 95° @ 11538' II J 218W — 13 - 1/2" X NP, D = 2.813" 1 Datum AU= 9841' - Da - tum ND = 8800' SS 10 -3/4" CSG, 45.5#, J-55, ID = 9.953' IH 3372 GAS LFT MANDRELS Baker 7 -5/8" x 5-1/2" ZXP LTP, ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3801 MMG w /C2 sleeve, 13Cr, -4,000' © 2 6080 KBG -2 -9 7 -5/8" CSG, 29.7 #, L -80 ABM BTC H 4498' I ' , ; 3 7533 KBG -2 -9 XO TO L -80 BTC ■ 4 8559 KBG -2 -9 Minimum ID = 2.813" @ 2189' 3 -1/2" HES X NIPPLE I 3 -1/2" X NIP, ID= 2.813" ►= -Baker 3-1/2" x 5-1/2" 13Cr SABL -3 5 -1/2 ", 17 #, L -80, TC Pkr -8,650', ID= 2.78" Ported seal stem I 868,T H7-5/8' X 5-1/2" ZXP LTP/ LNR HGR, D = 4.90" 3 -1/2" XN NIP, ID =2 3-1/2", 9.2#, 13Cr -85 VamTop -8,700' f ! I' 8706' (H5- 1/7 x3- 1/2"xO,D =2.97" 3-1/2" TBG, 93#, L -80 EUE 8RD, H 8722' I 8722' 1 W..E;, D = 2.992" .0087 bpf, D = 2.992" 3-1/2" Composite plug set at 8,800' -- Ii"" 'I I ( Top of Put River perfs at 8986' TOP OF 5-1/7 LNR H I 9012' I J 7 -5/8" CSG, 29.7 #, L -80 BTC, ID = 6.875" ---I 9296' , ■ 5-1/2" MLLOUTVIII'DOW (02 - 27A) 9673' - 9682' 4.75" WFPSTOCK H 9694' / 9900' ELM H3-1/7 VVFD CUP (08/01/09) EZSV -- I 9694' / PERFORATION SUMMARY ` REF LOG: SFERRY SUN NM'AYGR ON 10/21/99 ` ANGLE AT TOP PERF: 37° @ 8986' Note: Refer to Production DB for historical pert data SIZE S INTERVAL Opn /Sqz DATE SQZ 2" 6 8986 - 9010 C 08/01/09 , � = = . SIT 2 -1/7 4 11299 - 11745 C 11/24/99 PBTD H 11767' 'Mt.' 2 -1/7 4 10860- 11170 C 11/24/99 2-1/7 4 10140 10730 C 11/24/99 3-1/2" LNR, 9.2#, L -80 NSCT, .0087 bpf, D= 2.997 H 11860' 2 -1/7 6 10090 - 10115 C 06/27/02 2" 6 10022 - 10052 C 02/17/06 DATE REV BY COMMBJTS 01/04/10 CAV /PJC GLV GO DATE REV BY COMMENTS 03/26/11 BAY UNfT 1990 ORIGINAL COMPLETION 03/26/11 PJC LNR & TBG CORRECTION W�L 02 -27A 10/28/99 N7ES SIDETRACK 11/01/12 M5S/JM) GLV C/O (10/29/12) PERKY No: ° 1990930 11/15/12 RCT /JMD SET PX RUG & GLV GO (11/11-12/17 API No: 50- 029 - 21994-01 08/30/10 RCT /PJC TBG CORRECTIONS SEC 36, T11 N, R14E 434.93' FEL & 4869.5' FM_ 12/14 /10 CSR/PJC PERF CORRECTIONS (02/17/06) 03/25/11 GJF /PJC SETCUP(08 /01/09) BP Exploration (Alaska) RIG FLOOR 33.7 ' AGL I�� 1 _ j VALVE LEGEND 11E ©P ©P0� ©XO�QlI 1 BYPASS TI ' 2 KILL -11 rrai rrni li 3 CHOKE ,-- r 4 BOTTOM RAMS [ U� 5 BLIND RAMS 7 6 TOP PIPE RAMS • el 13 5/8", 5000 PSI, HYpBL ANNULAR BOP, ACCUMULATOR: NL SHAFFER, 180 GAL, 6 STATION 7 ANNULAR STUDDED TOP/FLANGED BOTTOM TRIPLEX PUMP: 575 VAC, 30 HP AIR PUMP: 1, NL SHAFFER - RANGED TOP 0 0 -/, . ill j &• 13 5/8', 5000 PSI, 10' MPL OPERATORS, j HYOPoL PIPE RAM 3 1/8" 5000 PSI SIDE OUTLET i 3' CHOKE UNE 13 5 /8 5000 PSI, 14' MPL OPERATORS. [ : : „„ �I •� • HNIPoL SURD SHEAR RNA 0 C - _ _ - _ _ - _ - _ BY PASS • • STUDDED BOTTOM BX 160 ♦ • � - • 3 1/8' 5000 PSI NCR VALVE 1500 3000 :, U �. IW 4 II'4III' 4III II,\II,.1111. 2" ALL UNE 3 1/8' 5000 PSI HCR VALVE- / / �HM■ 3 1/8' 5000 PSI GATE VALVE • • • • 3 1/8' 5000 PSI GATE VALVE �_� KIII •1111111111&• SINGLE 13 5/8', 5000 PSI, 10' MPL OPERATORS, r\���A lilnQn�i -a ' HN PIPE RAM STUDDED BOTTOM /F1ANGED TOP BX 180 • • - NMI ACCUMULATOR MANIFOLD ° DO 41111110 i1 18 BOTTLES, 10 GALLONS EACH ., -- • • ri -- x km t , BOP STACK ELEVATION [ - - - 3 REMOTE PANEL IN DOGHOUSE • j I AND UTII ITY MODUI E IA 111 NITROGEN BACKUP BOTTLES 21 1/4', 20°0 PSI, 18 150 PSI HYDR NSP HNIRIL BOP/DIVERTER ���" OPERATED KNIFE GATE VALVE ■mmmom STUDDED TOP/FLANGED BOTTOM 1" C/W PLUG IMMINI_ FLANGE /RANGE RX 73 THS a g1orBDBIrc OE51oA� sox ar mlal uuNC a ug K 18' FLC'D VENT UNE MM I 01/18/0B 5 VAR LEA SORTE BOP STACK RIG 14 I PROJECT _ 03/05/0 4 M B LEA WORM BOP KM ■M1101100 SCE 01/31/GB 3 0108 LEA Mac alai/IRL urn VILE BOP SYSTEM j 12 -20-00 2 DOB LEA SUITE BOP suck AND CONTROL SURFACE DIVERTER CONFIGURATION 11 -28 -15 1 ant LEE OMRTO 1.°1X1.° 71/28/98 RPR NFROWO" LEA wi '5 DATE 1..' V BV' acBVna 'A NTS Ma' JTIi4 R11480P5T5&CONTROL 1 r • i %C/( OZ -77f- 110 Pr i1`)cce tb Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] i oigtr, Sent: Monday, October 08, 2012 7:17 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS2 Operator; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; Russell, James; Daniel, Ryan Cc: AK, D &C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Producer 02 -27A (PTD #1990930) Sustained IA Casing Pressure Above MOASP Attachments: 02- 27A.pdf; 02 -27A TIO Plot 10- 08- 12.docx All, Producer 02 -27A (PTD # 1990930) has been found to have sustained casing_pressure on the IA above MOASP. The wellhead pressures were tubing /IA/OA equal to SSV /2020/VAC psi on 10/04/2012. The well failed a TIFL on 10/08/2012 indicating a lack of two competent barriers to formation. The well has been reclassified as Under Evaluation and may be produced while efforts to mitigate the communication are completed. The plan forward is: 1. Slickline: Change out orifice gas lift valve DINED APR 17 2013 2. Downhole Diagnostics: TIFL `cP A welibore schematic and TIO plot have been included for reference. ,1,4J't( .. 6 «02- 27A.pdf» «02 -27A TIO Plot 10- 08- 12.docx» Thank you, Mehreen Vazir BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWelIIntegrityCoordinator PBP.com Direct Cell: 832.651.5253 Direct Email: Mehreen.Vazir@'BP.com 1 PBU 02 -27A PTD #1990930 10/8/2012 TIO Pressures Plot ( Well 02 -27 I i � d.Q • I 1 I 1 1 3.000 - I I -- Tb0 i —II— IA I --4-- OA I 2.000 O i —4— OOOA n I 1 1 i 1 • I ■ 3 ti. .... .68....466 ► 6 . .6 . •• . 8..4 _ 46 . . . _ 6..4 . .4.4 a .84......... .. L D7/14 2 07/21/112 07128 08/04' 08311'1 08118/ 0825 09101t 09 /08/12 09/15172 09/22/12 09/29/12 10/x. + +1 .,, TREE = FMC GEN 4 • SAFETY NOTES: WELL ANGLE < 70° @ 10035' WELLHEAD = FMC ACTUATOR = AXELSON 02-27A KB. ELEV = 59.20' BF. ELEV KOP = 3931' Max Angle = 95° @ 11538' 2189' H3 -1/2" X NIP, ID = 2.813" I Datum MD = 9841' Datum TVD = 8800' SS 10 -3/4" CSG, 45.5 #, J -55, ID = 9.953" H 3372' I-, GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3791 3790 7 MMM DOME RK 16 01/04/10 7 -5/8" CSG, 29.7 #, L -80 ABM BTC -- 4498' 2 6933 6499 34 MMM DOME RK 16 01/04/10 XO TO L -80 BTC 3 8611 7893_ 34 MMM SO _ RK 22 01/04/10 Minimum ID = 2.813" @ 2189' 3-1/2" HES X NIPPLE �� � 8675' I- 17- 5 /8 "X4- 1 /2 "BKRS- 3PKR,ID= 3.875" TOP OF 3 -1/2" LNR I-1 8683' 1 8683' H7-5/8" X 5 -1/2" ZXP LTP/ LNR HGR, ID = 4.90" I I 8700' H3 -1/2" OTIS X NIP, ID = 2.813" ------ 8706' j- I5 -1/2" X 3 -1/2" XO, ID = 2.97" 3-1/2" TBG, 9.3 #, L -80 EUE 8RD, -I 8722' 8722' H3-1/2" WLEG, ID = 2.992" I .0087 bpf, ID = 2.992" I H ELMD TT NOT LOGGED I TOP OF 5 -1/2" LNR I-1 9012' I 17 -5/8" CSG, 29.7 #, L -80 BTC, ID = 6.875" H 9296' I 5-1/2" MILLOUT WINDOW (02 -27A) 9673' - 9682' i P = 1.600 ; 14.75" WHIPSTOCK H 9694' I 5 -1/2" EZSV I--I 9694' 9900' ELM I-13 -112" WFD CIBP (08/01109) PERFORATION SUMMARY REF LOG: SPERRY SUN MWD /GR ON 10/21/99 ` ANGLE AT TOP PERF: 37° @ 8986' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE sr► 2" 6 8986 - 9010 0 08/01/09 I PBTD -I 11767' I 7 2 -1/2" 4 11299 - 11745 C 11/24/99 2 -1/2" 4 10860 - 11170 C 11/24/99 2 -1/2" 4 10140 - 10730 C 11/24/99 13 -1/2" LNR, 9.2 #, L -80 NSCT, .0087 bpf, ID = 2.992" I—) 11860' 2 -1/2" 6 10090 - 10115 C 06/27/02 2" 6 10022 - 10052 C 02/17/06 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 1990 ORIGINAL COMPLETION 03/26/11 PJC LNR & TBG CORRECTIONS WELL: 02 -27A 10/28/99 N7ES SIDETRACK PERMIT No: 1990930 01/04/10 DAV /PJC GLV C/O API No: 50 -029- 21994 -01 08/30/10 RCT /PJC TBG CORRECTIONS SEC 36, T11 N, R14E, 434.93' FEL & 4869.5' FNL 12/14/10 CSR/PJC PERF CORRECTIONS (02/17/06) 03/25/11 GJF /PJC SET CIBP (08 /01/09) _ BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 22, 2011 E' S :P s ° O3 AUG Ntlt Mr. Tom Maunder Naha as Cow Alaska Oil and Gas Conservation Commission ' e 333 West 7 Avenue t Anchorage, Alaska 99501 (� 3 q -- Subject: Corrosion Inhibitor Treatments of GPB DS -02 • 7 , Dear Mr. Maunder, 0 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 2 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -326 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -336 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -346 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -356 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 • STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ~a~ ~~~~~ ~~~ ~~ £~Y ~ ~ 2~~~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG F ~ t,. ~, ~r~~~~i~~~~Y~ 1 a. Well Status: ~ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ZonAC zs.~os zonNC Zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. WeU Class k'~' °~' ~ Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP F~cploration Alaska) Inc. 5. Date Comp., Susp., or Aban 8/1/2009 12. Permit to Drill Number 199-093 309-206 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10l16/1999 13. API Number 50-029-21994-01-00 4a. Location of Well (Governmental Section): SurFace: ' ' 7. Date T.D. Reached 10/24/1999 14. Well Name and Number: PBU 02-27A 390 FNL, 818 FWL, SEC. 36, T11N, R14E, UM Top of Productive Horizon: 55' FNL, 1747' FEL, SEC. 35, T11 N, R14E, UM 8• KB (ft above MSL): 59.2' Ground (ft MSL): 30.7' 15. Fietd / Pool(s): Prudhoe Bay Field / Put River Total Depth: 410' FS~, 437' FEL, SEC. 26, T11 N, R14E, UM 9. Plug 8ack Depth (MD+ND) 11767' 8978' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 687554 y- 5950809 Zone- ASP4 10. Total Depth (MD+7yD) 11860' 8983' 16. Property Designation: ADL 028308 TPI: x- 684982 y- 5951081 Zone- ASP4 Total Depth: x- 686280 y- 5951578 Zone- ASP4 11. SSSV Depth (MD+ND) None 17. Land Use Permit: 18. Directional Survey ^ Yes ~ No ' I roni ri inf i n 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. ~ogs Obta+ned (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, CNL 22. CASING, LINER AND CEMENTING RECORD CASINCa SETfING DEPTH MD SETfING DEPTH ND HOLE AMOUNT - WTC PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMEN7'ING RECORD <` PULLED r 9. H-4 u 1' rf 110' " 11 0 1-/4" 7' ' 1 1" ~ooo ~ cs m, aso 5X ~c', 250 sx CS II (Top Job) 7- /8" .7# L- rf 9 9' rf 844 ' -7 " 0 s I '' 5-1/ " 17# 01 ' 7' 2' 7 7' -3/4" 1 x la ' ~~ . 1# / ' ' - /4~, ~ ~ 23. Open to production or inject ion? ~ Yes ^ NO 2~}. TUBING RECORD If Yes, list each i (MD+ND of To & Bottom; Pe nterval open rforation Size and Number): Size DePTH Ser nno PACKER SET MD p 6 spf Below Plug: 2-1/4~~ Gun Diameter, 4 spf 2" Gun Diameter 3-1 /2", 9.3#, L-80 8722' 8675' , MD TVD MD ND 8986~ - 901 ~~ 82~2' - s221 ~ 10140' - 10730~ s988~ - 9~~2~ 10860' - 11170' 9001' - 8996' 25. ACID, FRACTURE, CEMENT S~UEEZE, ETC. 11299~ -'I'I745' 8993~ - 5976~ DEPTH INTERVAL MD AMOUNT & KINO OF MATERIAL USED 9900' Set CIBP (Isolate Sadlerochit) cc~StSc.~G~~~C.J ~S~ 8986' - 9010' PerF Put River ~ ~tZ ~ i ZB. PRODUCTION TEST Date First Production: Au ust 4, 2009 Method of Operation (Flowing, Gas Lift, etc.): Flowin Dat@ Of T@St: 8/16/2009 HOUrS T@St@fI: $ PRODUCTION FOR TEST PERIOD OIL-BBL: 256 GAS-MCF: 40 WATER-BBL: 6 CHOKE SIZE: 84 GAS-OIL RATIO: 158 Flow Tubing Press. 724 Casing Press: 1,450 C~ucuwreo 24HouR RnTe• OIL-BB~: 767 GAS-MCF: 121 WATER-BBI: 18 Oll GRAVITY-API ~CORR~: Not Available 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ~ No Sidewal l Core s A uired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~~1q~ t~~p{§ YA.~I.G 1 lYtf~ N~nP. ~a ~ ~~~~.~i'w~" ; t.' ~ ~ , <'b (~ U~{? '~ ~" ~R h- ° f~ y ~ L~U~ ~ / ~~ _ ~ _ * ~ ....~ G Form 10-407 Revised 02/2007 CONTINUEO ON REVERSE SIDE ~~ '~~~~,/~`,~ ~ ~,. ~ c.~/ ZH. GEOLOGIC MARI~R3 ~LIST ALL FORMATIONS AND M ENCOUNTERED~: Z9. FORMATION TESTS NAME MD ND Well Tested? Yes ~ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Put River $892~ 8~26~ None Put River 8984' 8200' Base Put River 9010' 8221' Sag River 9190' 8362' Shublik 9238' 8399' Sadlerochit 9328' 8468' Below Window Sadlerochit / Zone 1 B 9957' 8931' Formation at Total Depth (Name): 30. List of Attachments: Summary of Non-Rig Workover Event Summary, Well Schematic Diagram 31. I hereby certify that the fore ng is a rrect to the best of my knowledge. Si ned ~ 9 Gary Preble Title Data Manager Date O l8 ~ PBU 02-27A 199-093 309-206 Prepared By Name/Number. Gary P~ble, 564-4944 Well Number Permit No. / A ~OV81 NO. Drilling Engineer: Claudie RiCO, 564-5628 (NSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITe~e 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements give~ in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Ire~ 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. lrEn~ 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IrEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Ir~M 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • ~ 02-27A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/30/2009;T/I/0= 740/1620/150. Temp= Hot. TIFL "*PASSED''* (Eval growing tree). ; No AL. Integral installed on IA. Initial IA FL @ 6933' SO (236 bbl). Shut in ;wing, stacked well out to 2250/1550/0+. Bled IAP from 1550 psi to 990 psi in ;1 hr. During bleed TP increased 10 psi, no change in IA FL. Monitored for 1 ; hr, TP increased 20 psi, no change in IA FL. Cellar depth is 20" conductor i size= 20" with open flutes and 12'3" of void (gravel bottom). Tree has grown 'to where the flutes are above conductor and moved back towar e o ~clock position, the flutes overhang the conductor from the 9 0' clock to the 3 o' clock position. Conductor sits 13" above surface. If vou push aaainst the 'SV,WV= C. SSV,MV= O. IA,OA= OTG. NOVP. ~ ~.~.~~._,_.._...~.~....~.~.~._. ~.P~e~ .~~~.~~ ..~.~~~_. 7/1/2009 T/I/O =2350/970/VAC. Temp=Sl. WHPs (TIFL). No AL. Integral installed on IA. TP decreased 530 psi, IAP decreased 20 psi, OAP went from 0+ to VAC `overnight. ~SV,WV=Closed. SSV,MV=Open. IA,OA=OTG. NOVP. 7/8/2009f****WELL S/I ON ARRIVAL'`""* i DRIFT TUBING W/ 2.70" CENT, 2.50" DUMMY GUN, TEL, S-BAILER TO ~9980' SLM/10006' MD STOP DUE TO DEV.(BAILER EMPTY) ; DRIFT TUBING W/ 2.75" CENT, 2.50" DUMMY GUN, S-BAILER TO 10000' 7/20/2009:T/I/0= 2220/1180/0 Temp= SI Assist E-line with Load and Kill- Pumped 5 ; bbls meth, 160 bbls seawater, 30 bbls crude and capped with 5 bbls meth. ; Final WHP's= 50/1220/0 "Operator notified of valves as SV,WV,SSV=closed, ' MV,IA and OA open on departure" ~ • 7/20/2009 ***WELL SHUT IN ON ARRIVAL*** ~~~~~~~~ RIG UP ~ CANCELLED OPERATION DUE TO CONFLICTS WITH RIG. ~ ; ~ ~ **"WELL SHUT IN ON DEPARTURE*** ~ ~ ~ ~ ~ ~ ~ ~~~ 7/30/2009 ~ I ~ ~ ~ ASRC Test Unit #2, MIRU, ***Job in Progress"** , i ~ i ~ ~ ~ ; ~ E ~ .. ~_ __ j 7/31/2009~ i ~ ~ ~ ~ ASRC Test Unit #2, Complete rig up, assist E-Line, '"**Job in Progress*** I ~ ~ ~ ~ ~ 7/31/2009 ~ i 3 **"WELL SHUT IN ON ARRIVAL INITIAL T/I/O: 2200/1500/0 PSI "** ~ ~ . . RIG UP ELINE TO SET WFD CIBP. SIMOPS WITH ASRC. i ~ RIH W/ TS: HEAD/ 2-1.69 IN WB/ CCU SAFE FIRING HEAD/BKR-05 ~ ~SETTING TOOU WFD 3.5" CIBP. ~ ~ 1 ~ ~ i"""JOB IN PROGRESS AND CONTINUED ON 01-AUGUST-2009.*** ~ ' 8/1/2009 ~ ~ ~ ~ j ASRC Test Unit #2, POP well, Start flowback, ***Job in Progress*** ~ ~ ~ I l ~ `'s ~_ _. ., i =, € i ~ ~ _r...__ ____ .~_ ~_..--- ~ _ ~ • ~ 8/1/2009 T/I/0= 2350/152p/0 Temp= S/I Assist E-line; Well Kill- Pumped 5 bbis ~ ~ 60/40 meth, 200 bbls sea water, 38 bbls crude and capped with 5 bbls 60/40 ? meth. *"IA & OA valves left open to gauges upon departure*" ~ i ~ f ~ ~ , ~ ~ ~ FWP's=100/1500/0 ~ 8/1/2009~ "**JOB CONTINUED FOR 31-JULY-2009.'"** (SET WFD CIBP, ~ , PERFORATE) I. ~ SET 3.5" WEATHERFORD CIBP AT 9900'. TAG PLUG TO CONFIRM ~ ~SETTING. ~ PERFORATE FROM 8986'-9010' WITH 2" POWERJET OMEGA HSD LOADED 6 SPF AND 60 DEG PHASING. i ~ PERFORATIONS CORRELATED TO MEMORY CNL DATED 22-NOV-1999. I API PENETRATION=21.8". API ENTRANCE HOLE=0.22". ` ~ TUBING PRESSURE 1NCREASED FROM 0 PSI TO 100 PSI AFTER ; FIRING AND 250 PSI AFTER REACHING SURFACE. ~ ~ WELL SHUT IN ON DEPARTURE. SSV, SWAB, AND WING VALVES ; s CLOSED. MASTER VALVE IS OPEN. j CASING VALVES ARE OPEN TO GAUGES. FINAL T/I/0=250/1500/0"*" , ~ _ ~ ***JOB COMPLETE"*" ~_ _~~__~~_~~ ~ ' i ^ TREE= FMCGENd W~LHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 59' BF. ELEV = KOP = 3931' Max Angle = 95 @ 11538' DatumMD= 9841' DatumND = 8800' SS 10-3/4" CSG, 45.5#, K-55, ID = 9.953" 34~' . 33'~Z' Minimum ID = 2.813" @ 2189' 3-1/2" HES X NIPPLE 02-27A SAFETY N0T6: HORIZONTAL W~L - 70° @ 10035 AND 90° @ 10261' 2189' ~'--~~1/2" X NIP, ID= 2.813" GAS LIFf MANDR~S ST WD ND DEV NPE VLV LATCH PORT DATE 1 3791 3790 7 MuIM LGLV RK 16 11/10/99 2 6933 6499 34 NMM LGLV RK 16 11/10/99 3 8611 7893 34 Mv1M DMY RK 0 04/22/03 7-5/8" X 4-1/2" BAKER S-3 RtR, W/XO 3-1/2" 1BG, 9.6Y~, L-80, .0087 bpf, ID= 3.992" 8722' • TOPOF 3-1/2" LNR 8725' TOPOF 5-1/2" LNR 9011' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" ~ 9296' 4.75" WHIPSTOCK 9694' ~~/2^ ¢SV H 9694' PERFORATION SUMM4 RY R~ LOG: SPERRY SUN MWD/GRON 10/21/99 ANGLEATTOP P92F: 77 @ 10090' Note: Refer to Ftoductbn DB for historical rf data SQE SPF INlERVAL Opn/Sqz DATE 2-1/2" 6 10090 -10115 O O6/27/02 ? 4 10140 - 10730 O 11 /24/99 ? 4 10860 -11170 O 11 /24/99 ? 4 11299 -11745 O 11/24/99 ~" L $Q$b' Q0~0 O$•01•0 ~ 8690' ~--I3-112" OTIS X NIP, ID = 2.813" $722' 3-1/2" 1lJBNGTAI~ ~WD Tf NOT LOGG~ ~~' C ~ ~P q+ 9900' Co8•o- •og~ I 11767' I &1r2" LNR, 9.2/#, L-80, .0087 bpf, ID= 2.992" ~-{ 11 QATE REV BY COMNENTS DATE REV BY COM~vENTS 1990 ORIGINAL COMREf10N 04/03/30 JM/fP GLV C/O 10/28/99 SIDETRACK 12/30/00 S6-SLT CONVERIEDTOCANVAS 02/21/01 SIS-LG REV ISION 02/27/02 RN/lP CORRECTIONS 06/27/02 PWEMK ADPERFS Pf~JDHOEBAY lRVff WELL: 02-27A P@2AAff Rb: 1990930 API No: 50-029-2199401 S~ 36, T11 N, R14~ 434.93' FEL & 4869.5' FNL BP Exploration (Alas ka) • ~ ~ ~ ~~ ~ ~ ~ ~ e ~ ~ °~ ~ ~ ~ ~ ~ ~ ~ ~ . SARAH PALIN, GOVERNOR ~~ OIIJ AID ~~ ai 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'1`IO1~T COMI~IISSIOIQ °° ANCHORAGE, ALASKA 99501-3539 ~~ PHONE (907) 279-1433 FAX (907) 276-7542 Claudia Rico Drill Site Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 ~~''` Anchorage, Alaska 99519-6612 , t Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 02-27A Sundry Number: 309-206 -ter ~ ~ , !~~, ~; ,~ 2DC >~~,'~ Dear Ms. Rico: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Comrrrission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of .this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair r DATED this Z 3 day of June, 2009 Encl. ~~ ~ ~aG~ STATE OF ALASKA ~ ~ V E D C~ ~ -~ l ALA OIL AND GAS CONSERVATION COMN~ION f U ti~ ~~ APPLICATION FOR SUNDRY APPROVAL 6~"~ °~`~~ ~ ~ ?009 ~~~ 20 AAC 25.28 r9~~lf~ I"9i1 ~i;;. I"9'~r r`nna (`nmmie~;. 1. Type of Request: ^ Abandon ^ Suspend ^ Ope~on_Shutdown ^ Perforate ^ Time Extensi y~~ ~~1C~60P8~ ^ Alter Casing ^ Repair Well ~Plu erforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ®Petfo1ate New Pool ^ Waiver ®Other ' ~•J/G e~-~ A raisal 2. Operator Name: 4. Current ell Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 199-093 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21994-01-00 ` 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: None PBU 02-27A Spacing Exception Required? ^ Yes ®No .~_r C!c~k~- '~!-I~~rccCGl'~!^ 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ~ ~rj ~ ex c~~~~ ADL 028308 ` 59.2' Prudhoe Bay Field / Prud 'Pool - 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11860' ~ 8983" 11767' 8978' None None Casin Len h iz MD TVD Bu C Ila S ructural Conu r 11 2 110' 11 14 47 Surface 3405' 10-3/4" 3372' 71' 358 20 0 Intermediate 9296' 7-5/8" 9296' 8443' 6890 479 P d i n Liner 661' 5-1/2" 9012' - 673' 8223' - 8737' 7740 6280 Liner 3177' 3-1/2" 8683' - 11860' 7953' - 8983' 7870 8640 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10090' - 11745' 8981' - 8977' 3-1/2", 9.3# L-80 8722' Packers and SSSV Type: 7-5/8" x 3-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 8675' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations. Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: June 30, 2009 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Claudia Rico, 564-5628 Printed Name Claudia Rico Title Drill Site Engineer ~ Prepared By Name/Number: ~ Signature ~:- 1 ~., Phone 564-5626 Date ~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: 7j (~'j .. ~® Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form Required: ~~~ APPROVED BY 2 ~~ A roved B COMMISSIONER THE COMMISSION Date Form 10-403 R~vfs~d~`/2006 ~ ~ ~ JUN ~ ~ 2D09 V [l S mit In Duplicate ~~ Memorandum ~g ,~ To: C. Olsen/J. Bixby Date: June, 2009 GPB Well Ops Team Leaders From: Claudia Rico- Code: PBD02WL27-C DS-02 & DS-05 Engineer Subject: 02-27A Put River Perforation & Anoraisal Please perform the following procedure: IOR: 600 Est. Cost: $250,000 1. S Drift to deviation. 2. T RU ASRC ortable test se arator and hook u oor bo as lift. 3. E RU a-line. Set cast iron bride lu .Perforate Put River interval at 8986' - 9010' md. 4. S Drift and run SBHPS 4. T Perform well test with ASRC se arator. Collect surface fluid sam les followin ASRC test. Current Status: Swing Last Test: 06/12/09 339 BOPD; 3 BWPD; 21,592 mscfd; WC: 1%; GOR: 63,768 Max Deviation: 95 deg @ 11538' Minimum ID: 2.813"@ 2,189' 3-1/2" HES X Nipple Last Downhole Op: 02/17/2006 Perforated From 10022' To 10052' Using 2" HSD 2506 PJ Omega. No Problems Reaching Required Depth. Tool Stopped Due To Deviation At 10078'. Confirmed Detonation Last TD Tag N/A Latest HZS Value: 03/30/2009 16 ppm O i This procedure intends to isolate the Ivishak formation and perforate the well 02-27A in the Put River Formation. Furthermore, contribute in the reservoir appraisal with fluids samples and SBHP data. it Well 2-27A was completed as a Z1A horizontal sidetrack in the Ivishak Formation on October 27, 1999. During the rig sidetrack, casing leaks were detected in the 7-5/8" casing at 8850' - 9200'. The 3-1/2" liner was set above the casing leaks and cemented with 56 bbls cement. 2-27A had a history of flowing at low oil rates with cold temperatures requiring frequent hot-oil treatments. In June 2002, 25' and (5' tvd) of Z1A heel perforations were shot along with a CT hot-oil wash. The perforations resulted in a significant increase in oil production which eliminated the need for hot oil treatments. Page 1 of 8 2-27A failed a TIFL in March 2003. A LIB run indicated a tubing restriction at 8450' and a cement sheath was broached with a 2.775" pineapple broach. The maximum OD drifted through the restriction was 2.625`'. The TIFL fluid levels indicated a slow leak at GLM #3. A DGLV was installed in GLM #3 and the well passed the subsequent TIFL. Slickline drifted a 2.25" centralizer and sample bailer drifted to 9944' SLMD in April 2004 in preparation for an RST and potential adperfs. An a-line RST ran on rollers in April 2004 indicated a gas under-run in upper Z1B. In July 2004, a-line drifted with a 2-1/2"dummy gun to adperfs but it was unable to pass due to deviation @ 9,994'. In January 16, 2006, drifted with a 2" dummy gun to 10,060' SLMD. In February, they shot 30' (10022' - 10052') adperfs (Z1B) using 2" HSD 2506 PJ omega. No problems reaching required depth. This job brought 250 IOR. 02-27A present day is a swing well, producer from the Ivishak, but the remaining value is low. Anew study to evaluate new wells for the Put River Formation showed the 02-27A as the best candidate to recomplete. In first instance the reservoir modeling indicated that putting 02-27A on production in addition to 02-23A (Put River well) adds rates and reserves. Furthermore, the well is mechanically fit for purpose. To complete this well in the Put River and contribute to the reservoir appraisal, it will follow these initial steps: 1. Isolate Ivishak formation with a composite bridge plug. '' 2. Perforate Put River. 3. Obtain SBHP 4. Get a well test with an ASRC test separator. 5. Collect surface fluid samples. For questions or comments please call Claudia Rico at x5626 or cell (720)951-3540 Cc: Well File Claudia Rico Page 2 of 8 PROCEDURE 2-27A Put River Perforation & Appraisal Slickline 1. Drift with 2"dummy gun to deviation. Well trajectory has an inclination of 54 degrees at 9,900' MD. ASRC Rig-up and E-Line Note: The ASRC test separator and poor-boy lift should be rigged up prior to rigging up a-line to perforate the well. This will enable the well to be POP'd without delay after perforating to minimize potential fluid damage to the formation. 1. Hookup surface lines for poor-boy gas lift. Gas lift will likely be required for the well. The gas lift design was installed on October 1999 and is adequate for the expected Put River rates. 2. RU ASRC test separator prior to rigging up a-line. This will enable the well to be POP'd immediately after perforating. 3. Kill well with filtered seawater to prevent formation damage after perforating. 5. Set cast iron bridge plug at 9900' md. 6. Run GR/CCL for tie-in log. Tie into Schlumberger's CNL/GR/CCL log dated November 22, 1999. Perforate Put River at 8986' - 9010' and (24') using 2" High Shot Density gun, Power ]et Omega 2006, HMX. 60° Phasing. 6 spf Slickline 1. Drift to top of 3-1/2" Liner @ 8725'. Get Bottom Hole Static Pressure as per procedure ASRC Well Test and Surface Fluid Sampling 1. POP well using ASRC test separator and test the well until stabilizes. Gas lift will likely be required. 2. At the conclusion of the ASRC test, collect fluid samples. 3. Return the well to the operator Page 3 of 8 PERFORATING PROCEDURE ADW ...._..~ Well: 02-27A API *: 50-029-2199401 Date: -------06/25/2009--_---- Prod Engr Claudia Rico----- Office Ph: 907-564-5626 _ H2S Level: --------- ---------- ----------------- -- -- Home Ph: - 16 (03130/09) CeIllPager: 720-951-3540 ------------------ CCorAFE: PBD02WL27-C ----------------------- WBL Entries IOR Type Work Desciption --'-------'i -"----------~---------------------- ----- ---------------'i 200 S Drift with 2" dummy gun to deviation 200 E ;Set cast iron plug at 9900' md. Perforate 8986' - 9010' md. The purpose of this procedure is to add 24' of perforations in the Put River Formation to increase the value of this well and enhanced the rates and rescues in the Put River. _ Note: Min ID = 2.813" @2189' 3-1-1/2" HES X Nipple. eterence Log ie in Log Add/Subtract feet Log: _ _ _ _ _ _ _ _ _ _ _ CNL/GR/CQ to the tie-in log to tie on Date: 11/22/1999 depth with the roferencs log. ----------------------- Company: SLB ---------- ----------- Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing Zone Ad/Re/Iperf 8,986' - 9,010' 24' 6 Random 60° Put River Add Requested Gun Size: 2" Charge: 2006PJ 4 Drewdown NecsssarylDssiradlUnneussary During Perforating Necessary _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Preferred Amount of DrewdownlSuggestions to Achiwe Drawdown ----------------------------------------------------- Last Tag: _ _ _ -nla _ _ _ it MD on WL _ _ _ n/a_ _ _ _ Het Rss. Pres. Q _ _ _ _ 8986' _ _ _ MD is -3800 _ _ _ psi Perforation Summary Summa Dist Well: 02-27A Town: Date: API #: 50-029-21994-01 Prod Engr: Anch Prod Engr ---------- -------- P.D. Center PBTD General Comments: ------------ ------------------------------------------------------------- --------- ------------------------------------ Depths ------------------------------------------------------------- --------- Balance Rebronced to BRCS Gun Dis. Orient. SPF Phasing Zone Adperf/Reperf O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - ---------- ------------ ---------- ~-- -g -- o/B/u - a e o 8 Page 5 of 8 Page 6 of 8 Company: BP Exploration Alaska 'v~Jel I : 02-27A Pertorating S~stem #3 2" High Shot Density, Po~verJet mega 2006, Htv~1X. 7.3 g 60° Phasing, 6.00 spf ~~ /~ ~-- / .' / ~/ 1 _ - _\ ~~. _ \ \ -~ \ ~\ ~ ~ ~~ ~ ~ '; ,. '; ~ , I i ',~ ~ -- ~" %`~ Rock Type' Sandstone \ ~ _ ~_ - _~ - ~- - / Rock UCS- 6403 psi \ ~ _~ vertical Stress: 8220 Psi '-- _ --~' Pore Pressure: 3585 psi _ Brine Cement Cement Damaged Zone Formation at 6.00 spf Page 7 of 8 AP1: Pen 21.80 in, EH Dia 0.22 in, 19B 1s: Ed. ' STATIC BOTTOM-HOLE PRESSURE SURVEY ~e~,4,R"vo,,,e,~oo~ Well: 02-27A API #: 50-029-21994-01 Date: 06/16/2009 Prod Engr Claudia Rico Office Ph: 584-5626 H2S Level; Cost Est: Home Ph: 16 (03130109) CC or AFE: PBD02WL27_R Cell/Pager:1720~51-3540 WBL Entries Type Work Description Comments S _ _ ;Drift to 3-1/2" liner top_~a 8,725'. Run ;This static pressure measurement will help to evaluate and monitor ; ~SBHP. .the current reservoir Wwll flhiacfiva¢ I nnninn Wnfa¢ and Rnacial In¢fnmfinn¢• Datum: 8100' SS Well Data Procedure: Last Tag: NA Tag date: NA 1. Make 10 min pressure stop in lubricator Max Deviation _ _95 Deis _ Depth: _ 11538' MD 2. Drop below the first pressure-stop requested. Pull-up to specified depth. 3. E/L: Measure pressure until it varies less than 1 psi in 20 min. Min. SI Time: 3 Days Loggin Data S/L: Hold guages at depth for time specified 4. E/L: Measure pressure until it varies less than 1 psi in 20 min. S/L: Hold guages at depth for time specified Requested Stops: MD SS Time 5. E/L: Measure pressure until it varies less than 1 psi in 20 min. First 8983' ------------------- 8140' -------- 15 min ------------- S/L: Hold guages at depth for time specified Second 8995' 8150' 15 min 6. EIL: Test tool in lubricator at 3000 psi with calibrated test gauge Third 9014' 8180' 15 min S/L: Hold guages in lubricator for 10 min stop. Compare to test guage Fourth 8995' 8150' 40 min 7. Leave well shut in if SBHP is less than N/A Well: Date: Service Co. Date 02-27A API #: 50-029-21994-01 ---------------------------- New Tag: 'MD Time Type of Pressure Tool SITP (Tubing): Upper Lower PE Summa Dist Town: Anch Prod Engr P.D. Center MD SS Gauge Gauge Temperature Test Gauge Pre-Job Lubricator Pressure 8983' 8140' 8995' 8150' ----------- -------- -------------------------------------- 9014' 8160' ----------- -------- --------------------------------------- 8995' 8150' Post-Job Lubricator Pressure Shut In Date: ---------------------------------- Comments: and Time: --------------------------------------------------------------------------------- Total Shutln Time(hrs~- -----------------------------------------------------------Page 8_of-8--------- TREE= ` FMC GEN 4 :NELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 59' BF. ELEV.... KOP = 3931' ____. Max Angle = 95 @ 11538' Datum MD = 9841' Datum TV D = 8800' SS 10-3/4" CSG, 45.5#, K-55, ID = 9.953" 3372' O ~ -2 7A A @ 0~2`61HORIZONTAL WELL - 70° @ 10035' 2189' I~ 3-1/2" X NIP, ID = 2.813" GAS LIFT MANDRELS Minimum ID = 2.813" @ 2189' 3-1/2" HES X NIPPLE ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3791 3790 7 MMM LGLV RK 16 11/10/99 2 6933 6499 34 MMM LGLV RK 16 11/10/99 3 8611 7893 34 MMM DMY RK 0 04/22/03 8674' I~ 7-5/8" X 4-1/2" BAKER S-3 PKR, W/XO 3-1/2" TBG, 9.6#, L-80, .0087 bpf, ID = 3.992" I $722' TOP OF 3-1/2" LNR 8683' TOP OF5-1/2" LNR 9012' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" ~ 9296' 4.75" WHIPSTOCK 9694' 5-1/2" ¢sv I~ 9694' PERFORATION SUMMARY REF LOG: SPERRY SUN MWD/GRON 10/21/99 ANGLE AT TOP PERF: 77 @ 10090' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 10090 - 10115 O 06/27/02 ? 4 10140 - 10730 O 11/24/99 ? 4 10860 - 11170 O 11/24/99 ? 4 11299 - 11745 O 11/24/99 8700' -I3-1/2" OTIS X NIP, ID = 2.813" 8722' 3-1/2" TUBING TAIL ELMD TT NOT LOGGED TOW at 9673` PBTD I-{ 11767' 3-1/2" LNR, 9.2#, L-80, .0087 bpf, ID = 2.992" I--I 11860' DATE REV BY COMMENTS DATE REV BY COMMENTS 1990 ORIGINAL COMPLETION 04/03/30 JNVTP GLV C/O 10/28/99 SIDETRACK 12/30/00 SIS-SLT CONVERTED TO CANVAS 02/21/01 SIS-LG REVISION 02/27/02 RN/TP CORRECTIONS 06/27/02 PWE/KK ADPERFS PRUDHOE BAY UNff WELL: 02-27A PERMff No: 1990930 API No: 50-029-21994-01 SEC 36, T11 N, R14E, 434.93' FEL & 4869.5' FNL BP Exploration (Alaska) i • Review of Sundry Application 309-206 BP Exploration (Alaska) Inc. Well PBU 02-27A AOGCC Permit 199-093 Requested Action: BP Exploration (Alaska) Inc. (BPXA) proposes to plug the existing wellbore in the Prudhoe Oil Pool (POP) and perforate the Put River Oil Pool (PROP). Recommendation: I recommend approval of Sundry Application 309-208 to allow BPXA to perform this operation. Discussion: This well (02-27A) has not been a huge producer over its lifetime, from November 1999 to Apri12009, but has consistently produced at least 300 bopd since January 2006. This is in part due to the 25 foot (md) perforations shot in the heel in June 2002 and 30 foot (md) perforations shot in January 2006. The decline of oil production began directly after each perforation was shot. After the second perforations were shot, the rate of production went from 420 bopd and a GOR of 51.1 Mcf/bbl in January 2006 to 327 bopd and 60.9 Mcf/bbl GOR in April 2009. See Appendix A. Although the GOR was high throughout this time period, production time also stayed high with 4 months having less than 22 days of production. Using only the production since the 2006 perforations, Appendix B, the reservoir shows that 776.5 Mbbl would remain using this current decline. 02-27A has recovered 1,416 Mbbl since November 1999. With each perforation shot, the decline in bopd is similar to this data, which shows that the decline given is probable. After talking with Claudia Rico from BPXA, it was apparent that the Ivishak formation was not to be neglected indefinitely. BPXA was very aware of the value of the Ivishak formation and would access it at a later time. As for now, this well is better used for the PROP. The POP formation would be plugged only with a CIBP at 9900' (md) which allows for easy access when it is to be decided to reproduce the POP. Conclusion: BPXA realizes the potential and value of the Ivishak formation, but also believes that this well can be more efficiently utilized in the PROP. With this information given, I agree with BPXA's choice to temporarily plug the POP and perforate the PROP. I recommend approving BPXA's request. • College Intern AGOCC Aaron Kohring _ as q L,,, ' 7 11 I concur~this statement ? Reservoir Engineer AOGCC ~~ ~~ ,/~y David Roby ~ ~ ~~i'~`~ :,~?,,~~ G'' -~`?~~ ~- 4 • Appendix A .~ s s Appendix B A STATE OF ALASKA I AlAW\ Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS D D o ,,' '" 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 59.2 KB 8. Property Designation: ADL-028308 11. Present Well Condition Summary: Total Depth measured 11860 true vertical 8983.47 Effective Depth measured 11767 true vertical 8978.44 Casing Conductor Surface Production Liner Length 80 3376 9268 662 Size 20" 91.5# H-40 10-3/4" 45.5# J-55 7-5/8" 29.7# L-80 5-1/2" 17# L-80 Perforation depth: Measured depth: 10022 - 10052 True Vertical depth: 8962.46 - 8972.13 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 345 338 x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development RJ Stratigraphic r feet feet feet feet MD 30 - 110 29 - 3405 28 - 9296 9011 - 9673 10090 -10115 8980.77 - 8985.87 3-1/2" 9.3# RECEIVED APR 0 4' " Stimulate D Other Q WaiverD Time ~~~ (jag Cons. Commissi n Re-enter Suspended Well D Anchora 5. Permit to Drill Number: Exploratory Service 199-0930 6. API Number: 50-029-21994-01-00 9. Well Name and Number: 02-27 A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) None None TVD Burst Collapse 30 - 110 1490 470 29 - 3404.48 3580 2090 28 - 8443.48 6890 4790 8221.73 - 8737.29 7740 6280 10140 - 10730 8989.61 - 9002.91 10860 -11170 9002.36 - 8996.89 11299 - 11745 8993.95 - 8977.32 L-80 26 - 8722 4-1/2" Baker S-3 Perm Packer (~t··t.ì. ~1~Î~;f) ,,,,,vj¡~1:':"f'" ,,, Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 22771 10 0 23457 6 0 15. Well Class after proposed work: Exploratory r Development RJ¡ 16. Well Status after proposed work: Oil RJ¡ Gas WAG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal ~ _ c "-.7,/#./J signat~~~ / -it' 8674 Tubing pressure 716 727 Service WDSPL Title Data Mgmt Engr Phone 564-4424 Date 4/3/2006 \- " APR 5 2006'~, Submit Original Only Form 10-404 Revised 04/2004 .. e e 02-27 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE I~;µM_¡Y ;1 2/16/2006 PERFORATED FROM 10022' TO 10052' USING 2" HSD 2506 PJ OMEGA. NO PROBLEMS REACHING REQUIRED DEPTH. TOOL STOPPED DUE TO DEVIATION AT 10078'. STANDBY FOR LRS TO LOAD TUBING. ***CONTINUED ON NEXT DA Y*** 2/17/2006 *** CONTINUED FROM PREVIOUS DAY*** PERFORATED FROM 10022' TO 10052' USING 2" HSD 2506 PJ OMEGA. NO PROBLEMS REACHING REQUIRED DEPTH. TOOL STOPPED DUE TO DEVIATION AT 10078'. CONFIRMED DETONATION OF ALL RUNS AFTER POOH. NO PROBLEMS POOH. WELL TURNED OVER TO DSO. JOB COMPLETE. FLUIDS PUMPED BBLS 1 I ::::L 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ¡'1:; --éi:3 E-36 ?,:;,~cE Z-05 8'j -CI-NR-13 Vff. /e 7 02-07 A :elf- }/3 N-01A ;1Ltt~f L5-05 ~ [.,-[(;'7 F-27 (L- 0;1 D.S.06-14A 71-(/í'!J D.S. 02-27 A '13~-I2) D.S. 03-22 ~2 - D15E-08A rtf -iJ7 .- E-19A 15-02. ~ C-08A Well Job # 10679044 10679035 10772272 10772244 10877782 10679070 10662946 10563157 10772247 10687697 10728384 10678042 10728385 SCANNEC jUN 1 7 2005 Log Description RST RST RST RST RST RST RST RST RST RST MCNL RST MCNL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~!ø5 ~!J~ / j /cr7-ð? 3 02/03/05 NO. 3327 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Prints CD 12/25/03 1 1 11/28/03 1 1 06/06/04 1 1 04/07/04 1 1 08/27/04 1 1 04/05/04 1 1 09/13/03 1 1 05/13/03 1 1 04/10/04 1 1 07/20/04 1 1 01/01/04 1 1 12/21/03 1 1 01/03/04 1 1 - Alaska Data & Consulting Services 2525 Gambell Street., Suite 400 í Anchorage, AK 995-0.... 3-2838 / ¡ .. ATTN: ~~ J //1 // / Rec-<::d.bY: / ~ . t~4t~ "(e' , ( ç STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ - Stimulate_ Plugging _ Perforate _X Add Perfs Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5.. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 59 feet 3. Address Explorato~_._ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 391' FNL, 4462' FEL, Sec. 36, T11 N, R14E, UM (asp's 687554, 5950809) 02-27A At top of productive interval 9. Permit number / approval number 4935' FNL, 2235' FEL, Sec. 26, T11 N, R14E, UM (asp's 684484, 5951469) 199-093 At effective depth 10. APl number 4888' FNL, 528' FEL, Sec. 26, T11 N, R14E, UM (asp's 686189, 5951557) 50-029-21994-01 At total depth 11. Field / Pool 4870' FNL, 437' FEL, Sec. 26, T11 N, R14E, UM (asp's 686280, 5951578) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11860 feet Plugs (measured) true vertical 8983 feet Effective depth: measured 11767 feet Junk (measured) true vertical 8978 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 1125# Poleset 144' 144' Surface 3338' 10-3/4" 1000 sx CS III, 350 sx 3372' 3371' 'G', 250 sx CS II Intermediate 9262' 7-5/8" 300 sx Class 'G' 9296' 8443' Liner 661' 5-1/2" 125 sx Class 'G' 9012'- 9673' 8223'- 8737' Sidetrack Liner 3177' 3-1/2" 288 sx Class 'G' 8683' - 11860' 7953' - 8983' Perforation depth: measured Open Perfs 10090'-10115', 10140'-10730', 10860'-11170', 11299'-11745' true vertical Open Perfs 8981'-8986', 8988'-9002', 9001'-8996', 8993'-8976' R E (~ E i V ED Tubing (size, grade, and measured depth) 3-1/2", 9.6#, L-80, TBG @ 8722' MD JUL 1 6 20O2 Packers & SSSV (type & measured depth) 7-5/8" x 3-1/2" Baker S-3 PKR @ 8674'. 3-1/2" X Nipple @ 2189' MD. Alaska 0il & Gas Co~s. 6om~nissiof 13. Stimulation or cement squeeze summary Anchora0e Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or I niection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 06/24/2002 387 8512 6 250 Subsequent to operation Shut-In 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is t,r,,ue and correct to the best of my knowledge. DeWayne R. Schl'iorr ~ Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · ORIGINAL SCANNED JUL 3 1 2002 SUBMIT IN DUPLICATE 02-27A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/29/2002 06/05/2002 06/25/20O2 06/26/2002 06/26/2002 O6/27/2002 DRIFT/TAG (RATE): DRIFT/TAG HOT OIL TBG WASH: HOT OIL TREATMENT HOT OIL TBG WASH: HOT O];L TREATMENT HOT OZL TBG WASH: HOT OIL TREATMENT; PERFORATING HOT OTL TBG WASH: HOT OIL TREATMENT PERFORATING: HOT OIL TREATMENT; PERFORATING EVENT SUMMARY O5/29/02 TAG PARAFIN @ 1285' SLM W/3.50 CENT - TAG PARAFIN/HYDRATES @ 3270' SLM W/2.50 CENT - AND TAG HYDRATES @ 3285' W/2.07 GAUGE RING (GAUGE RING "PACKED FULL" OF HYDRATES". WELL BOL. 06/05/02 HOT OIL WASH TUBING AND FLOWLINE. 06/25/02 HOT OIL WASH TUBING AND FLOWLINE. 06/26/02 MIRU #3. WEEKLY BOP TEST, GOOD TEST. RU HBR, RIH AND HOT COIL TUBING WASH TO REMOVE PARIFFIN. 06/26/02 PUMPED 303 BBLS HOT DSL DOWN TBG TO ASSIST CTU. 06/27/02 CONTINUED WASHING TUBING, EXISTING PERFS AND NEW PERF AREA. NO OBSTRUCTIONS ENCOUNTERED IN/OUT OF HOLE. POOH. PU SWS MEMORY GR/CCL. RIH AND LOG TIE-IN INTERVAL 10150'-9950', PAINT FLAG. POOH. PU GUNS, RIH TO FLAG, CORRECT COIL DEPTH. RIH TO SHOOT DEPTH. SHOT 10090'- 10115' WITH 2-1/2" PJ 2506 HMX, 6 SPF, RANDOM SHOT ORIENTATION. POOH. GUNS FIRED. RDMO. <<< LEAVE WELL FLOWING, NOTIFY DSO OF STATUS. >>> Fluids Pumped BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 0 TEST) 40 50/50 METHANOL WATER 290 KCL WATER 593 DIESEL 276 CRUDE 1199 TOTAL ADD PERFS O6/27/2OO2 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2-1/2" PJ2506 HMX, 6 SPF, 60/120 DEGREE PHASING, RANDOM ORIENTATION. 10090' - 10115' Page I SCANNED JUL 3 1 2002 TREE = FMC GEN 4 WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 59' BE ELBA/= KOP = 3931' Max Angb = 95@11538' Datum MD = 9841' DatumTVD = 8800' SS 10-3/4" CSG, 45.5#. K-55, ID = 9.953" H 3405' Mini,m. um ID = 2.813" @ 2189' 3-1/2 HES X NIPPLE 02-27A SAFETY NOTES: HORIZONTAL WELL 70° @ t0035' ANO 90° ~ 10261' 2189' 1--13-1r~"XNIP, ID=2.813'I GA S LIFF MANDRELS TVD DB/ TYpE VLVlLATCH PORT DATE 3791 3790 7 k~MM I F~ 6933 6499 34 MMM ~ 8611 7893 34 [v~VlM I~K , 8674' H7-5/8" X4-1/2"BAKERS-3 PKR, W/XO I 3-1f2" TBG, 9.6#, L-80..0087 bpf. ID = 3.992" ]'~ 8722' ITOPOF 3,1/2" LNRH 8725' ITOP OF 5-1/2" LNRH 9011' L7-5~,, c~G, 99.7¢, L-80, ,D = 6.875" I--I~1 14.75" WHIPSTOCK Id 9694' 86~o' 1-13-1~" OT~SX N,P,,D =2.613" I 87=,~I~"~B~GTA,L 1 HEL~TN°TL°~ I PEREORATtON SUMMA RY RB= LOG: SPSRRY SUN MWD/G R ON 10/21/99 ANGLEATTOR P~F: 77 @ 10090' Note: Refer to Produc~on DB for historical perf data SIZ. E SPF INTER~AL l op~¢sq~l DATE 2-I/2" 6 10090 - 10115 O 06/27/02 7 ] 10140-10730 O 11/24/99 ? 4 10860 - 11170 O 11/24/99 11299 - 11745 O 11/24/99 11767' I 3-1/2" LNR. 9.2~, L-80, .0087 bpf, ID= 2.992" 11860' DATE REV BY COMMENTS 1990 ORIGINAL COMPLETION 10128199 SIDETRACK 02/27/02 RN/TP COP-RECTIONS 12/30/00 StS-SLT CONVERTED TO CANVAS 02/21/01 SIS-LG REVISION "' ]0~2 ~ A~ERESCO~ I PRUDHOE BAY UNIT WELL: 02-27A PERMIT No: 199-0930 APl No: 50-029-21994-01 SEC 36. T11 N, RI4E 434.93 FEL 4869.5 FNL BP Exploration (Alas k a) Permit to Drill No. 1990930 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Well Name/No. PRUDHOE BAY UNIT 02-27A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-21994-01-00 MD 11860 TVD 8983 Completion Date 11/24/1999 ' Completion Status 1-OIL Current Status I-OIL UIC N REQUIRED INFORMATION Mud Log No Samples N~o Directional Survey No DATA INFORMATION (data taken from Logs Portion of Master Well Data Maint) Types Electric or Other Logs Run: Well Log Information: kogl Data Digital Digital Interval Log Log Run OH / Dataset Type Media Format Name Scale Media No Start Stop CH Received Number Comments ~-- ........ a,~;,~MC ~i~_ .................. ~ ........... ~iNAL 8635 ...... i-i:747 CH 2/1-~200(~ ...... 1'~/-22/99 ~ DeR-MD 25 FINAL 9673 10244 OH 4/28/2000 ~~R-TVD 25 FINAL 8736 8991 OH 4/28/2000 ~ .~RVY RPT 59 11860 OH 11/18/1999 SPERRY 9664.. ~-. O ~~550 9673-11819 Well Cores/Samples lnforaatiom Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Daily ltistory Received? .~¢,~/N Formation Tops Receuived? Y~N Comments: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 April 27, 2000 RE: MWD Formation Evaluation Logs ' D.S. 02-27A, AK-MW-90163 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off :Fun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, fiG, Anchorage, AK 99518 D.S. 02-27A: 2"x 5" MD Gamma Ray Logs: 50-029.21994-01 2" x 5" TVD Gamma Ray Logs: 50-029-21994-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia APR 28 2eO Alaska Olt & Gas Cons. commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 2-27A, April 18, 2000 AK-MW-90163 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-21994-01. -PR 2 4 000 Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company Schlumberger NO. 121179 2/9/00) Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 2-30A (REDO) LEAK DETECTION LOG 000128 I 1 D.S. 15-30 ~ c.~q~(,.;, 99463 ~PERF DEPTH CONTROL MEMORY GR 991115 I I 1 D.S. 18-07 ~_, ;~"~ 20005 RST-SIGMA 991128 I I 1 D.S. 2-27A ~d~j61 ~'-~ 99451 MCNL 991122 I I 1 D C~l: I\1i: [t SIGNED DATE: Naska Oil & Gas Co,~, c. ommi~lon Anchorage Please sign and return one ci3'py of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [~] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 199-093 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21994-01 4. Location of well at surface . · . '.,- 9. Unit or Lease Name 390' SNL, 818' EWL, SEC. 36, T11 N, R14E, UM "' : ~' ~ ': ~"!~~i Prudhoe Bay Unit At top of productive interval 10. Well Number 345' NSL, 2235' WFL, SEC. 26, T11N, R14E, UM 02-27A At total depth i ~~' i L~~i ll. Field and Pool 412' NSL, 439' WEL, SEC. 26, T11N, R14E, UM Prudhoe Bay Field / Prudhoe Bay 5. I:levation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBI: = 59.20'I ADL 028308 12. Date Spudded10/16/99 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re j 16' N°' °f C°mpleti°nsl 0/24/99 11/24/99 N/A MSLI One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Survey F0. Depth where SSSV set 121. Thickness of Permafrost 11860 8983 FTI 11767 8978 FTI (~]Yes I--I No (Nipple) 2189' MD 1900' (Approx.) 22. Type I:lectric or Other Logs Run MWD, GR, CNL 23. CASING, LINER AND CEMENTING RECORD U ~ CASING SE-I-FING DEPTH HOLE 1 '~ SIZE WT. PER FT. GRADE TOP BO-FFOM SIZE CEMENTING RECORD ~ ~JJ~,T ~IJJ,.I.~E D,, ,,. 20" 91.5# H-40 Surface 110' 30" 1125# Poleset(I'[. ~ I ~/I' !) 10-3/4" 45.5# J-55 Surface 3372' 13-1/2"1000 sx CS III, 350 sx 'G', 250 sx CS II 7-5/8" 29.7# L-80 Surface 9296' 9-7/8" 300 sx Class 'G' 5-1/2" 17# L-80 9012' 9673' 6-3/4" 125 sx Class 'G' DEC 3-1/2" 8.8# / 9.2# L-80 8683' 11860' 4-3/4" ~88 sx Olass 'G' Aj.~ka,'" " ............. ~11 & ua~ bUlls, L, Ulliiiil~lUi 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/4" Gun Diameter, 4 spf 3-1/2", 9.3#, L-80 8722' 8675' MD TVD MD TVD 10140' - 10730' 8988'- 9002' 10860' - 11170' 9001' - 8996' 26. AO~D, FRACTURE, CEMENT SQUEEZE, ETC. ,, 11299' - 11745' 8993' - 8976' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 100 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) November 26, 1999 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. iD 24-HOUR 28. RATE CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Sag River 9190' 8284' Shublik 9238' 8399' Sadlerochit 9328' 8468' Zone 1 B 9957' 8930' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the ,orego~g ~s true and correct to the best of my knowledgeSigned "~0,~C~ ~(~..~J~~'~ ?? Terrie Hubble -- _, .~, Title Technical Assistant III Date __' I~' 02-27A 199-093 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. I'rEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. RECEIVED 1999 Alaska 011 & Gas Cals, Com An ora Form 10-407 Rev. 07-01-80 Progress Report Facility PB DS 02 Well 02-27A Page 1 Rig Nabors 7ES Date 28 October 99 Date/rrime 06 Oct 99 03:00-06:00 03:00-06:00 06:00-06:00 06:00-09:00 09:00 09:00-15:00 15:00 15:00-20:30 20:30 20:30-06:00 07 Oct 99 06:00-06:00 06:00-14:30 14:30 14:30-00:00 08 Oct 99 00:00 00:00-03:00 03:00 03:00-06:00 06:00 06:00-12:00 06:00-12:00 12:00 12:00-01:30 12:00-22:00 Duration 3hr 3hr 24 hr 3hr 6hr 5-1/2 hr 9-1/2 hr 24 hr 8-1/2 hr 9-1/2 hr 3hr 3hr 6hr 6hr 13-1/2 hr 10hr Activity Move rig Rigged down Drillfloor / Derrick R/D 9ES. Prep rig 7ES to move to DS 2. Move rig (cont...) Rigged down Drillfloor / Derrick Cont'd to prep rig for cold stack. Removed subs and handling tools from rig floor. Prep mud pumps and cent pumps. Equipment work completed Rig moved 100.00 % Move shop pits and camp. Transport camp and pits to DS-2. Remove herculite in units due to wind. Move rig sub base off well and park behind rig crew camp on W pad, derrick up. P/U herculite. Rig off station Rig moved 2.00 % Transport crew to rig 7ES at CC2-a. Clean up oil around back wheel area. Jack up sub, clean under sub beams. Move rig and cut up herculite as go. Rig off station Rig moved 50.00 % Pulled rig out onto spine road. Wait on security. Moved rig 7ES to Oxbow road cutoff, old guard shack, at report time. Move rig (cont...) Rig moved 95.00 % Finished moving sub to DS 2. Parked rig at end of pad while pre-rig work continues. Rig off station Rigged up Drillfloor / Derrick Fire boilers. Remove ice and snow from derrick and windwalls. Grease and inspect sheaves. Held PJSM and raised derrick. (Finished move pit module to DS 2) R/U floor and straighten up lines in derrick. Bridle down and pin blocks to top drive. Work completed - Drillfloor / Derrick in position Rigged up Mud pumps Assemble mud pumps, shakers, and centrifuge. Cont'd to clean up on rig floor. Stopped due to weather: Unsafe to continue operation Rig waited ' Weather Pre rig well work completed. Unable to remove well house due to wind. Clean and organize rig while waiting on clearance from operator to remove wellhouse. Resumed operations Derrick management Rigged down Drillfloor / Derrick Moved crew back to 9ES on W-pad. Turn rig so could lay down derrick. Unhook top drive, bridle up blocks, lay down derrick. Equipment work completed Move rig Rig moved 100.00 % Crew -'~ ...... "'~'° -- ~'° 2. ' -' ,~.,~,,~ ,,[ ,,,o ,,, ~o ,.ew, pad, lay mats and Progress Report Facility PB DS 02 Well 02-27A Page 2 Rig Nabors 7ES Date 28 October 99 Date/Time 22:00 22:00-22:30 22:30 22:30-01:30 09 Oct 99 01:30 10 Oct 99 01:30-03:00 01:30-03:00 03:00 03:00-06:00 03:00-06:00 06:00-19:00 06:00-10:00 10:00 10:00-12:00 12:00 12:00-16:00 16:00 16:00-16:30 16:30 16:30-19:00 19:00 19:00-06:00 19:00-22:00 22:00 22:00-04:00 04:00 04:00-06:00 04:00-06:00 Duration 1/2 hr 3hr 1-1/2 hr 1-1/2 hr 3hr 3hr 13hr 4hr 2hr 4hr 1/2 hr 2-1/2 hr llhr 3hr 6hr 2hr 2hr Activity herculite. Spot sub over well. Spot mud pits, At well location - Cellar Held safety meeting Held pre-spud safety meeting. Discuss well plan, work remaining to be completed prior to rig accept, start of operations. Completed operations Installed Fluid system Work on pumps, lines, alarms, finish secure herculite berms. Start taking water into pits. Equipment work completed Rig accepted 0100 hrs, 10/9/99 on DS 2-27A. Wellhead work Removed Hanger plug R/U DSM lubricator and pulled BPV. Equipment work completed Fluid system Fill pits with Seawater R/U to tree to circulate. Finish taking on seawater. Check mudlines, finish work on pumps. Wellhead work Installed High pressure lines Work on pumps. R/U choke and kill lines to circulate well. Installed annulus valve. Equipment work completed Tested High pressure lines Filled pump and lines with water and tested to 3000 psi. Fill choke lines and gas buster with water and check for leaks. Pressure test completed successfully - 3000.000 psi "~ Circulated at 8722.0 ft CBU 5 bbls/min, 500 psi. Shut in and circ thru choke, gas and oil in returns. Circ until got clean returns. Hole displaced with Seawater - 150.00 % displaced Installed Hanger plug Set BPV. Eqpt. work completed, running tool retrieved Removed Xmas tree N/D tree and adapter. Installed blanking plug. Equipment work completed Nipple up BOP stack Installed BOP stack Installed 1 l"x 13 5/8" adapter and BOP stack. R/U flow nipple. Equipment work completed Rigged up All rams Open ram doors and installed 2-7/8"x 5" VBR top, blind shear in middle, and 2-7/8"x 5" rams bottom. Close and tighten doors. Equipment work completed Tested BOP stack R/U and test BOP's, Testing at report time. Tested BOP stack Tested pipe rams, blind rams, hydril, choke and RECEIVED Facility Date/Time 11 Oct 99 PB DS 02 Progress Report Well 02-27A Page 3 Rig Nabors 7ES Date 28 October 99 06:00-09:30 06:00-09:30 09:30 09:30-11:30 09:30-11:30 11:30 11:30-05:30 11:30-13:00 13:00 13:00-14:30 14:30 14:30-15:30 15:30 15:30-21:00 21:00 21:00-22:00 22:00 22:00-05:30 05:30 05:30-06:00 05:30-06:00 05:30-06:00 06:00-08:00 06:00-08:00 08:00 08:00-15:00 08:00-12:30 12:30 12:30-15:00 Duration 3-1/2 hr 3-1/2 hr 2hr 2hr 18hr 1-1/2 hr 1-1/2 hr lhr 5-1/2 hr lhr 7-1/2 hr 1/2 hr 1/2 hr 2hr 2hr 7hr 4-1/2 hr 2-1/2 hr Activity Performed accumulator test. BOP tests witnessed by C. Nipple up BOP stack (cont...) Tested BOP stack (cont...) Tested pipe rams, blind rams, hydril, choke and kill lines, floor safety valves to 250/3500 psi. Performed accumulator test. BOP tests witnessed by C. Scheve, AOGCC. Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug R/U and pulled FMC blanking plug. Pulled BPV w/ lubricator. Equipment work completed Pull Gas lift completion, 4-1/2in O.D. Installed Drillpipe retrieval string P/U 4" drill pipe landing it. Screwed into hanger and pulled hanger to floor. 170K max pull, 120K P/U with top drive. Stopped: To circulate Circulated at 8722.0 ft CBU 7 bpm, 625 psi. Obtained bottoms up (100% annulus volume) Rigged up Tubing handling equipment Finish R/U to lay down tubing. Equipment work completed Laid down 3090.0 ft of Tubing L/D 77 its 4-1/2" tubing. Spooling SSSV and chemical injection lines. Stopped: To change handling equipment Rigged up Tubing handling equipment Change to 3-1/2" tubing handling equipment and changeout camco spooling unit. Equipment work completed Laid down 3255.0 ft of Tubing L/D 105 jts 3-1/2" tubing and chemical injection line. Stopped: To service drilling equipment Repair Repaired Tubing handling equipment Repair hydraulic block on pipe skate. Repaired Tubing handling equipment ~.C 1 5 1999 Finished repairs to hydraulics on pipe skate. Repair (cont...) Repaired Tubing handling equipment (cont...) ~01] & (~a$C3~15. Cd)IT Finished repairs to hydraulics on pipe skate. .~or~t~ Equipment work completed Pull Gas lift completion, 3-1/2in O.D. Laid down 2410.0 ft of Tubing Finished L/D 3-1/2" tubing, 178 jts total 3-1/2" recovered. Recovered (79) 4-1/2" metal clamps, (181) metal 3-1/2" clamps, (22) SS bands for 100% recovery. Stopped · To change handling equipment Rigged down Tubing handling equipment R/D camco spooling unit and Nabors casing tools. RECEIVED Facility Date/Time 12 Oct 99 PB DS 02 Progress Report Well 02-27A Page 4 Rig Nabors 7ES Date 28 October 99 15:00 15:00-15:30 15:00-15:30 15:30 15:30-06:00 15:30-17:00 17:00 17:00-01:00 01:00 01:00-06:00 06:00-08:00 06:00-07:30 07:30 07:30-08:00 08:00 08:00-09:30 08:00-09:30 09:30 09:30-15:00 09:30-10:00 10:00 10:00-14:00 14:00 14:00-15:00 15:00 15:00-02:30 15:00-18:00 18:00 18:00-18:30 18:30 18:30-19:00 19:00 19:00-19:30 19:30 19:30-20:30 Duration 1/2 hr 1/2 hr 14-1/2 hr 1-1/2 hr 8hr 5hr 2hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 5-1/2 hr 1/2hr 4hr lhr 11-1/2 hr 3hr lhr Activity Equipment work completed Wellhead work Installed Wear bushing Eqpt. work completed, running tool retrieved BHA run no. 1 Made up BHA no. 1 P/U packer milling BHA. BHA no. 1 made up Singled in drill pipe to 8746.0 ft P/U drill pipe. Tagged packer on depth. At Top of packer: 8746.0 ft Milled Permanent packer at 8749.0 ft Milling packer rubber at report time. Packer appears to be spinning. BHA run no. 1 (cont...) Milled Permanent packer at 8749.0 ft Completed operations Milled on permanent packer. Completed milling operations. Circulated at 8749.0 ft In 0.50 hr had 12.000 bbl Gain - closed in well Circulate bottoms up and observe 12 bbl gain- gas bubble beneath packer. Close well in. Well control Circulated closed in well at 8749.0 ft Gas at surface Circulate out gas bubble from well thru choke. Flowcheck- hole static. BHA run no. 1 Circulated at 8749.0 ft Obtained req. fluid properties - 100.00 %, hole vol. Open well, Circulate and flowcheck well- ok. Pulled out of hole to 400.0 ft At BHA Pulled BHA BHA Laid out Pull BHA and lay down mill- Good even wear. Boot Baskets full- approximately 15 lbs. BHA run no. 2 RECEIVE[ Made up BHA no. 2 BHA no. 2 made up Make up 4.010" spear assembly and RIH to 7~j ~O~).~t. ] 5 1999 Serviced Block line Line slipped Slip 40 ft. R.I.H. to 8700.0 ft At Top of fish: 8700.0 ft RIH and take parameters. 178 klbs up, 150 klbs down. Break circulation @ 2 BPM/325 psi. Fished at 8745.0 ft Fish came free Engage fish and seat grapple. Freed up with 20 klbs overpull. Fish 5 ft high. Circulated at 8745.0 ft on Facility PB DS 02 Progress Report Well 02-27A Page 5 Rig Nabors 7ES Date 28 October 99 Date/Time 13 Oct 99 14 Oct 99 20:30 20:30-01:00 01:00 01:00-02:30 02:30 02:30-06:00 02:30-03:00 03:00 03:00-06:00 06:00-15:30 06:00-06:15 06:15 06:15-06:30 06:30 06:30-07:00 07:00 07:00-07:30 07:30 07:30-10:00 10:00 10:00-12:30 12:30 12:30-15:30 15:30 15:30-06:00 15:30-17:00 17:00 17:00-20:00 20:00 20:00-22:00 22:00 22:00-01:00 01:00 Duration 4-1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr 3hr 9-1/2 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 3hr 14-1/2 hr 1-1/2 hr 3hr 2hr 3hr Activity Obtained bottoms up (100% annulus volume) Pulled out of hole to 200.0 ft Fish at surface Laid down fish Complete fish recovered Lasy down packer and remainder of fish, total length 80 ft. Tubing cut clean. BHA run no. 3 Made up BHA no. 3 BHA no. 3 made up Make up BHA # 3. Overshot w/3.5" grapple. TOF estimated at 8827'. R.I.H. to 7800.0 ft RIH with overshot assembly. BHA run no. 3 (cont...) R.I.H. to 8820.0 ft At Top of fish · 8820.0 ft Fished at 8830.0 ft Fish came free Take parameters and wash over fish @ 48 spin/200 psi. Latch same and pull free. Circulated at 8830.0 ft Obtained bottoms up (100% annulus volume) Serviced Top drive Equipment work completed Pulled out of hole to 1100.0 ft At BHA Pulled BHA BHA Laid out Pull BHA and release grapple. Laid down fish RECE[¥ Complete fish recovered Lay down tailpipe fish. 2 x 3.1/2" jts, 1 x GLM, 26 x 2.7/8" tubing, 12' cut. Total length @ 927.61'. ] § 19' TOF @ 9,757.61' Electric wireline work Rigged up Logging/braided cable equipment Equipment work completed Conducted electric cable operations Observed 1.50 klb overpull RIH with 4.75" gauge ring and junk basket. No problems down to 9,743'. Tight coming out @ 9,743, 9,670, 9630,. Able to free up going down. Acting like draggging junk up hole. Pulled completely free @ 9,325'. Went to 75% pull each time ( 4000 lbs tension) Test Computer hardware unit Function test completed satisfactorily Replace rope socket and trouble shoot conductivity problems with wireline. Resolve same. Conducted electric cable operations Completed run with Junk basket/gauge ring from -0.0 ft to 9735.0 ft Run 4.75" gauge ring and junk basket. Enter 5.5" liner @ 9,008' after several attempts. Tight on bottom @ 9,735'. Pull free and repeat log over interval Cl~"tt~ (%~/'~C'' .-.:*k~..* .... £..--*k ..... kl~--~ 'l~t'-At'~TT t-AT/" J..JLLJ--.>' / ..)J VYItllkJLtL Ctll.y ILIII. IIGI I. JIUL/IGIII3, I k-./k./tl- Ulna., ED¸ Facility PB DS 02 Progress Report Well 02-27A Page 6 Rig Nabors 7ES Date 28 October 99 Date/Time 01:00-04:00 04:00 04:00-06:00 06:00-08:00 06:00-08:00 08:00 08:00-09:00 08:00-09:00 09:00 09:00-12:30 09:00-12:30 12:30 12:30-13:00 12:30-13:00 13:00 13:00-02:00 13:00-18:30 18:30 18:30-18:45 18:45 18:45-19:30 19:30 19:30-20:00 20:00 20:00-20:30 20:30 20:30-22:30 22:30 Duration 3hr 2hr 2hr 2hr lhr lhr 3-1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 13hr 5-1/2 hr 1/4 hr 3/4 hr 1/2 hr 1/2 hr 2hr Activity Junk basket empty. Test Winch unit Function test completed satisfactorily Unable to get satisfactory surface test thru wireline cable. Troubleshoot and resolve same at "collector". Set downhole equipment (wireline) M/U 5.5" bridge plug EZSV and RIH. At 7800' at report time. Loosing 1-2 bbls/hr. Electric wireline work (cont...) Set downhole equipment (wireline) Completed run with Bridge plug to 9694.0 ft RIH and correlate wireline to CBT log of 1990 and sonic log. Set EZSV @ 9,694'. S/O and ensure BP set. POOH and R/D Schlumberger. Perform integrity test Tested Bridge plug Suspended function test, problems encountered Attempt to test wellbore and bridge plug to 3000 psi- no go. Bleeding off at 150 psi/min. Doublecheck all surface equipment, confirm downhole. Wellhead work Installed Seal assembly Equipment work completed Remove 7.5/8" pack-off and replace same. Test to 5000 psi OK. Install wear ring. Perform integrity test Tested Casing Suspended pressure test on Casing, observed leak Attempt to test casing- no go. 150 psi/min leak rate. 4in. Packer assembly workstring run Ran Drillpipe to 8850.0 ft (4in OD) RECEIVED Packer set at 8850.0 ft Stage Champ III packer into well and test casing at 2000 ft, 6000 ft and 8850 ft to 3000 psi. Good [.", EC 1 § 199 tests. Set packer at 8940.0 ft with 0.0 psi Packer set at 8940.0 ft Tested Casing Suspended pressure test on Casing, observed leak Test backside. Casing leaking, 50 psi/min. Open rams and test below packer- leaking at 150 psi/min - returns at surface indicating bad 7.5/8" casing above 5.5 "liner top. Release packer with 15 klbs overpull, unable to go down. POOH to 8,850'. Set packer at 8850.0 ft with 0.0 psi Packer set at 8850.0 ft Tested Casing Pressure test completed successfully - 3000.000 psi Successful test to 3000 psi/30 minutes, Pulled out of hole to 3500.0 fl Stopped: To service drilling equipment Facility PB DS 02 Progress Report Well 02-27A Page 7 Rig Nabors 7ES Date 28 October 99 Date/Time 15 Oct 99 16 Oct 99 22:30-00:00 00:00 00:00-02:00 02:00 02:00-06:00 02:00-06:00 06:00-06:00 06:00-10:30 10:30 10:30-11:00 11:00 11:00-11:30 11:30 11:30-13:00 13:00 13:00-19:30 19:30 19:30-21:30 21:30 21:30-00:00 00:00 00:00-00:30 00:30 00:30-03:00 03:00 03:00-06:00 06:00-06:30 06:00-06:30 06:30 06:30-06:00 06:30-09:00 Duration 1-1/2 hr 2hr 4hr 4hr 24 hr 4-1/2 hr 1-1/2 hr 6-1/2 hr 2hr 2-1/2 hr 1/2 hr 2-1/2 hr 3hr 23-1/2 hr 2-1/2 hr Activity Serviced Block line Line slipped and cut Cut 85 ft and slip 45 ft Pulled out of hole to -0.0 ft At BHA POOH and L/O Champ IH packer. BHA run no. 4 Made up BHA no. 4 MFU 4.75" Whipstock assembly, orientate and check MWD at report time. BHA run no. 4 (cont...) R.I.H. to 8800.0 ft At Top of liner: 8800.0 ft RIH checking MWD @ 4,000 ft and filling pipe at 8,800 ft - above corroded 7.5/8" casing. Orientate whipstock. R.I.H. to 9690.0 ft Began precautionary measures Run carefully into 5.5" liner- no resistance. Break circulation and orientate whipstock. Functioned downhole tools at 9694.0 ft Equipment work completed S/O and set bottom anchor with 10 klbs weight. Confirm anchor set. Attempt to shear bolt by s/o 40 klbs- no shear seen, expected with 25 klbs weight. Circulated at 9694.0 ft Hole displaced with Water based mud - 120.00 % displaced Displace well to 8.3 ppg QuikDrill mud @ 4% lubricants @ 3.8 BPM/1100 psi. '~ Milled Liner at 9673.0 ft Completed operations Milled window from 9,673' to 9,685 ft. Milled formation to 9,698'. Smooth parameters- window clean. Bolt must have sheared when setting bottom anchor) Circulated at 9698.0 ft Obtained bottoms up (100% annulus volume) Sweep hole clean. Pulled out of hole to 3000.0 ft Stopped: To hold safety meeting Held safety meeting Completed operations Hold Safety Meeting and familiarise new crew wit~j~ 7es. Pulled out of hole to 800.0 ft At BHA Pulled BHA L/D Drillcollars and milling BHA. Mills in good conditon. 4in. Drillpipe workstring run Circulated at 50.0 ft Choke & kill line flushed Flush BOP stack. BHA run no. 5 Made up BHA no. 5 RECEIVED 9 Facility PB DS 02 Progress Report Well 02-27A Page 8 Rig Nabors 7ES Date 28 October 99 Date/Time 09:00 09:00-11:30 11:30 11:30-12:00 12:00 12:00-13:30 13:30 13:30-14:30 14:30 14:30-17:30 17:30 17:30-06:00 17 Oct 99 06:00-21:30 06:00-11:00 11:00 11:00-11:30 11:30 11:30-12:30 12:30 12:30-15:00 15:00 15:00-18:00 18:00 18:00-21:30 21:30 21:30-02:00 21:30-02:00 Duration 2-1/2 hr 1-1/2 hr lhr 3hr 12-1/2 hr 15-1/2 hr 5hr lhr 2-1/2 hr 3hr 3-1/2 hr 4-1/2 hr 4-1/2 hr Activity BHA no. 5 made up MFU 4.75" Kick off assembly. Orientate and check MWD/Motor- OK. Singled in drill pipe to 1520.0 ft 45 joints picked up Single in 45 joints 2.3/8" HT drillpipe making up with Hydraulic tong. Circulated at 1520.0 ft String displaced with Water based mud - 200.00 % displaced Circulate string contents and check MWD- OK. R.I.H. to 5300.0 ft Stopped: To service drilling equipment Serviced Top drive Equipment work completed R.I.H. to 9698.0 ft On bottom RIH to above whipstock. Orientate. Run to bottom and start drilling. Drilled to 9948.0 ft Kick off 4.75" hole. Average doglegs @ 24 degrees placing trajectory insidse target ploygon but just outside drillers polygon. Cut pumps f/130 to 120 GPM when smaller doglegs noted. No drag, no losses. BHA run no. 5 (cont...) Drilled to 10010.0 fl Walk & build rate unacceptable - BHA Slide ahead 4.75" monitoring surveys. DLS dropped to 21 degrees- unable to acheive directional objective. Bit hours 12.9, 90,000 revs. Circulated at 10010.0 ft Obtained req. fluid properties - 20.00 %, hole vol. Circulate 50 bbls ( x2 open hole and liner volume) and prepare to POOH to above liner so angle would not be washed away. Pulled out of hole to 8800.0 ft At Top of liner: 8800.0 ft POOH slowly to above bad section of 7.5/8" casing @ 8800 ft. Pull slowly watching for swabbing tendencies. Circulated at 8800.0 ft Obtained bottoms up (100% annulus volume) 3999 Circulate bottoms up @ 132 GPM/1150 psi. Flowcheck. Pulled out of hole to 1520.0 ft At BHA Pulled BHA BHA Stood back Pull 2.3/8" pipe and BHA. Motor in good condition ( wear 1/16"- same as before run). Bit in good condition- bearings effective, in gauge. BOP/riser operations - BOP stack Tested BOP stack RECEIVED Facility PB DS 02 Progress Report Well 02-27A Page Rig Nabors 7ES Date 9 28 October 99 Date/Time 18 Oct 99 19 Oct 99 02:00 02:00-06:00 02:00-06:00 06:00-06:00 06:00-09:30 09:30 09:30-11:00 11:00 11:00-12:00 12:00 12:00-06:00 06:00 06:00-23:00 06:00-07:30 07:30 07:30-08:30 08:30 08:30-10:00 10:00 10:00-10:30 10:30 Duration 4hr 4hr 24 hr 3-1/2 hr 1-1/2 hr lhr 18hr 17 hr 1-1/2 hr lhr 1-1/2 hr Activity Pressure test completed successfully - 3500.000 psi Pull wear ring. Change out saver sub on top drive. Test BOPE and function test accumulator. Install wear ring. AOGCC, John Spalding waived witness. BHA run no. 6 Made up BHA no. 6 Make up new BHA. Change out jars, bit. Include PBL sub and adjust dend to 2.77 degrees. RIH w/2.3/8" HT drillpipe picking up 1700 ft. Tested choke manifold on trip out. No Losses. Hole good on trip out. BHA run no. 6 (cont...) R.I.H. to 9000.0 ft RIH w/4" DP from Derrick. Fill Pipe at 5000' and 8000'. Downhole measurement tools failed - Circulate Functioned Downhole measurement tools No signal from MWD. Dropped ball to open PBL. Dropped ball to close PBL. Orient to go out window. Equipment work completed R.I.H. to 10000.0 ft RIH. Resistance at 9917'. Kelly up and check orientation. Wash through to bottom. On bottom Drilled to 10170.0 ft Drill ahead. Slow ROP in shale. ROP picked up around 4:00. Began precautionary measures BHA run no. 6 (cont...) Worked stuck pipe at 10110.0 ft Pipe came free Pump back on a con. and pack-off @ 10,110'. Unable to move pipe. ( 30 klbs o/pull, 40 klbs slack-off). Unable to fire jars down. Apply 6,000 ftlbs RH torque w/35 klbs slacked off, jars fired- free pipe. Circulate.Free pipe again when at same point Circulated at 10170.0 ft RECF_.IVI Obtained req. fluid properties - 80.00 %, hole vol. Circulate and work pipe below problem zone. [' 7 ~ Top 13N Shale @ 10,010', Bottom @ 10ta08~fll Pulled out of hole to 9673.0 fl At top of check trip interval POOH without pumps. Take one hour to work pipe thru 10,110 to 10,095 w/15 klbs o/pull. Work thru tight interval several times- OK.Another tight spot @ 10,040'. Rest hole OK. R.I.H. to 10170.0 ft On bottom RIH- no problems. D ~mi~0n Facility PB DS 02 Progress Report Well 02-27A Page 10 Rig Nabors 7ES Date 28 October 99 Date/Time 20 Oct 99 10:30-13:30 13:30 13:30-14:00 14:00 14:00-15:00 15:00 15:00-16:00 16:00 16:00-19:00 19:00 19:00-19:30 19:30 19:30-23:00 23:00 23:00-06:00 23:00-01:30 01:30 01:30-06:00 06:00-06:00 06:00-07:00 07:00 07:00-07:30 07:30 07:30-08:30 08:30 08:30-06:00 08:30-06:00 Duration 3hr 1/2 hr lhr lhr 3hr 1/2 hr 3-1/2 hr 7hr 2-1/2 hr 4-1/2 hr 24 hr lhr 1/2 hr lhr 21-1/2 hr 21-1/2 hr Activity Drilled to 10230.0 ft Reached planned end of run - Directional objective met Drill from 10170' to 10230'. Circulated at 10230.0 ft Circulated 4 OH volumes to avoid cuttings beds and to condition shale above. Obtained bottoms up (100% annulus volume) Pulled out of hole to 10230.0 ft Stopped · To circulate POH to 8760'. No problems. 5K over pull. Drop ball to open PBL sub. Circulate at 6 bpm @ 1150 psi. Circulated at 8760.0 ft Obtained bottoms up (100% annulus volume) CBU. Monitor well. Pulled out of hole to -0.0 ft At BHA POH wet to BHA. Monitor well Rigged up Drillstring handling equipment Equipment work completed RD 4" handling equipment and RU 2 3/8" equipment. Pulled BHA Stand back 2 3/8" DP. LD DDS super slim vibration tool, jars, PBL, and break bit. Straighten motor and lay it down. Clear and clean floor. Load new BHA. BHA Laid out BHA run no. 7 Made up BHA no. 7 MFU bit, STB sleeve, change out mud motor, orient MWD and RIH 1 stand and shallow hole test. BHA no. 7 made up R.I.H. to 7000.0 ft RIH with 2 3/8" DP from derrick and PU 39 singles from shed. Test MWD. RIH with 4" DP. Fill pipe at 6000'. BHA run no. 7 (cont...) Serviced Block line Line slipped and cut crown-o-matic.CUt and slipped 80' of 1 1/4" drilling line. CNecRFC~,~, Removed Top drive Remove corrosion ring from XO in top drive. Fill Pipe and orient. Equipment work completed R.I.H. to 10230.0 ft RIH. Stage pump. Wash 45' to bottom. On bottom Drilled to 10500.0 ft Continue drilling. Still tough sliding. 20-30 klbs overpulls picking up off bottom. No good "sets". Drilled to 10500.0 ft Drill with PDC from 10230' to 10500' at report time. Drlg in Zone 1. Slow and difficult slide drilling. Maintain mud lubricant concentration of 6%. ED Facility PB DS 02 Progress Report Well 02-27A Page 11 Rig Nabors 7ES Date 28 October 99 Date/Time 21 Oct 99 06:00-06:00 06:00-07:00 07:00 07:00-08:00 08:00 08:00-10:00 10:00 10:00-15:30 15:30 15:30-16:30 16:30 16:30-17:00 17:00 17:00-18:30 18:30 18:30-06:00 22 Oct 99 06:00-06:00 06:00-06:00 23 Oct 99 06:00-06:00 Duration 24 hr lhr lhr 2hr 5-1/2 hr lhr 1/2 hr 1-1/2 hr 11-1/2 hr 24 hr 24 hr 24 hr Activity BHA run no. 7 (cont...) Drilled to 10500.0 ft (cont...) Drill with PDC from 10230' to 10500' at report time. Drlg in Zone 1. Slow and difficult slide drilling. Maintain mud lubricant concentration of 6%. Have increase ROP in sand sections to 70-90 ft/hr. Stopped: To circulate Circulated at 10500.0 ft Circulate while rotating and reciprocating to clean hole. Pump Pressure rapidly increased 300 psi. All other parameters stable. Obtained bottoms up (100% annulus volume) Pulled out of hole to 9670.0 ft Short trip back into 5 1/2" liner. Hole in good condition. No over pulls. At Window: 9670.0 ft Drilled to 10559.0 fl Slide from 10,500' to 10,510'. Pump stick-less glass beads to aid in sliding. Add 15 lbs/bbl beads to make 20 bbl slurry. No problems exiting BHA. Rotate pipe w/o pumping to place beads. Repeat process @ 8 ppb @ 10,534' Began precautionary measures RECEiV1ED Took MWD survey at 10559.0 ft Began precautionary measures Take surveys. Azimuth readings indicating "kick" th:--i" right, opposite direction of BHA orientation. Repeat surveys. AI~ 0~1 & Ga8 G011s,C Drilled to 10576.0 ft Stopped: To take survey Drill ahead in rotary mode to see effects of slide and determine if BHA underperforming. Took MWD survey at 10576.0 ft Acceptable survey obtained at 10528.0 ft Repeat surveys and verify that BHA turning 8 degrees/100 left when sliding. 5 degrees/100 to right when rotating. Suspect geological problem not mechanical. Drilled to 10830.0 ft Drill to 10830' at rpt. time. Adding 5 sacks barofiber per hr, and pumping stick-less beads as needed to aid sliding. Maitain 5.5% lubricants in mud. 20-25 klb over pulls while picking up during slides. BHA run no. 7 (cont...) Drilled to 11330.0 ft Drill to 11,330' at rpt. time. Got hung up at 11256' while sliding. Had beads dwn hole. Tried to pull free w/40 klb over pull. S/o off, rotated & pipe came free. Rot. ahead to get to cleaner sand before cont to slide. BHA climbing 3 deg rotating. BHA run no. 7 (cont...) Facility Date/Time 24 Oct 99 25 Oct 99 PB DS 02 Progress Report Well 02-27A Page 12 Rig Nabors 7ES Date 28 October 99 06:00-06:00 06:00-06:00 06:00-11:30 11:30 11:30-13:30 13:30 13:30-15:30 15:30 15:30-16:30 16:30 16:30-18:15 18:15 18:15-18:30 18:30 18:30-21:30 21:30 21:30-22:45 22:45 22:45-23:00 23:00 23:00-01:30 01:30 01:30-06:00 06:00 06:00-06:30 06:00-06:30 06:30 06:30-00:30 Duration 24 hr 24 hr 5-1/2 hr 2hr 2hr lhr 1-3/4 hr 3hr 1-1/4 hr 1/4 hr 2-1/2 hr 4-1/2 hr 18hr Activity Drilled to 11740.0 ft Drill to 11,740' at rpt. time. Pump high viscosity sweep every 3 or 4 hrs. Pump bead sweep prior to slides. BHA drilling straight when rotating. Drill into cleaner sand at 11500' & having overpulls. Suspect diff. sticking. Minimize w/ barofiber. BHA run no. 7 (cont...) Drilled to 11860.0 ft Reached planned end of run - Section / well T.D. Directionally drill 4.75" hole f/11,780' to 11,860'. No losses. No drag. Reach TD as per Geological instrucutions. Circulated at 11860.0 ft Obtained bottoms up (100% annulus volume) Sweep hole while working/rotating pipe, racking stands every hour. Circulate @ 155 GPM/2000 psi. Off bottom torque @ 3000 ftlbs @ TD. Pulled out of hole to 9685.0 ft At top of check trip interval Make short trip to window. Some 10-15 klbs "tugs" f/11,180'-11,090'. Work thru same. Hole in good shape. R.I.H. to 11860.0 ft On bottom No problems. Circulated at 11860.0 ft Hole swept with slug - 50.00 % hole volume Circulate x 4 open hole volumes & spot 50 bbls[.., .-i~ ~ ~ 1999 Liner running pill w/5% lubricants. Flow check Observed well static Flowcheck well- hole static. Pulled out of hole to 8700.0 ft Stopped: To circulate POOH. Hole in good shape. Average drag 5 klbs less with new mud in open hole. Pull above bad spot in 7.5/8". Circulated at 8700.0 ft Obtained bottoms up (100% annulus volume) Open PBL and circulate bottoms up. Flow check Observed well static Pulled out of hole to 3000.0 ft At BHA POOH to 2.3/8". Laid down 3000.0 ft of 2-3/8in OD drill pipe R/U and POOH laying down 2.3/8" drillpipe and BHA. Began precautionary measures BHA run no. 7 (cont...) Pulled BHA Finish LD BHA. Clear floor. BHA Laid out Run Liner, 3-1/2in O.D. RECEIVED AlliSka Oil & Gas Certs. Corn ion Facility PB DS 02 Progress Report Well 02-27A Page 13 Rig Nabors 7ES Date 28 October 99 Date/Time 26 Oct 99 06:30-08:00 08:00 08:00-08:30 08:30 08:30-14:00 14:00 14:00-15:00 15:00 15:00-21:00 21:00 21:00-21:30 21:30 21:30-22:00 22:00 22:00-00:30 00:30 00:30-06:00 00:30-05:15 05:15 05:15-06:00 06:00 06:00-08:00 06:00-06:30 06:30 06:30-08:00 08:00 08:00-09:00 08:00-09:00 09:00 09:00-17:30 09:00-11:00 11:00 Duration 1-1/2 hr 1/2 hr 5-1/2 hr lhr 6hr 1/2 hr 1/2 hr 2-1/2 hr 5-1/2 hr 4-3/4 hr 3/4 hr 2hr 1/2 hr 1-1/2 hr lhr lhr 8-1/2 hr 2hr Activity Rigged up Casing handling equipment RU to run 3.5" liner. Work completed - Casing handling equipment in position Held safety meeting Completed operations Ran Liner to 3188.0 ft (3-1/2in OD) Ran total of 69 jts 3.5", 9.3#, L-80, NSCT & 29 jts 3.5", 9.3#, L-80, ST-L. MU hanger & liner top packer. Hanger assembly installed Circulated at 3200.0 ft Circ liner volume. Hole displaced with Water based mud - 120.00 % displaced Ran Drillpipe in stands to 9650.0 ft Rabbit 30 stds DP. At Window: 9673.0 ft Rigged up Cement head MU cement head on single. Lay out in skate. PU single & pup in string. Work completed - Cement head in position Circulated at 9673.0 ft Circ string volume @ window. Broke circulation Ran Drillpipe in stands to 11860.0 ft Liner ran good to 11,210'. Worked past numerous '. tight spots on last 7 stds. Worked down with no circulation-OK. On bottom Cement:Liner cement AII~0[lt~0 Circulated at 11860.0 ft Broke circ slowly. Gradually worked rate up to 5 bpm. PJSM & batch mixed slurry while circ. Obtained clean returns - 300.00 % hole volume Mixed and pumped slurry - 59.000 bbl Pumped 50 bbls 9.5# Spacer followed w/59 bbls (283 sxs)Premium 'G' @ 15.8#. Released Wiper plug Cement: Liner cement (cont...) Displaced slurry - 113.700 bbl Displace with Dowell. Plug bumped at calculated volume. CIP 0615 hrs. Set hanger and packer, rotated off liner hanger. Plug bumped Ckculated at 8680.0 ft Circ 5 bbls cmt from top of liner, changeover to seawater. Hole displaced with Seawater - 100.00 % displaced Perform integrity test Tested Liner Tested liner and lap to 3000 psi for 30 rain, OK. Pressure test completed successfully - 3000.000 psi Pull Drillpipe, 4in O.D. Laid down 2573.0 ft of 4in OD drill pipe Stopped: To service drilling equipment RECEIVED '9 Facility Date/Time 27 Oct 99 PB DS 02 Progress Report Well 02-27A Page 14 Rig Nabors 7ES Date 28 October 99 11:00-12:00 12:00 12:00-17:30 17:30 17:30-18:00 17:30-18:00 18:00 18:00-06:00 18:00-18:30 18:30 18:30-19:00 19:00 19:00-06:00 06:00 06:00-12:30 06:00-07:30 07:30 07:30-08:30 08:30 08:30-10:30 10:30 10:30-12:30 12:30 12:30-15:30 12:30-13:00 13:00 13:00-15:30 15:30 15:30-18:30 15:30-18:30 18:30 18:30-20:00 18:30-20:00 20:00 20:00-21:30 Duration lhr 5-1/2 hr 1/2 hr 1/2 hr 12hr 1/2 hr 1/2 hr llhr 6-1/2 hr 1-1/2 hr lhr 2hr 2hr 3hr 1/2hr 2-1/2 hr 3hr 3hr 1-1/2 hr 1-1/2 hr 1-1/2 hr Activity Serviced Block line Line slipped and cut Laid down 6483.0 ft of 4in OD drill pipe 292 joints laid out Wellhead work Removed Wear bushing Equipment work completed Run Gas lift completion, 3-1/2in O.D. Rigged up Tubing handling equipment Equipment work completed Held safety meeting Completed operations Ran Tubing to 8725.0 ft (3-1/2in OD) Finish running tubing at 0600 hrs. Space out. Stopped: To pick up/lay out tubulars Tagged up, ready to space out. RECEIVED Run Gas lift completion, 3-1/2in O.D. (cont...) Space out tubulars L/D tubing jt. P/U hanger and landing jt. Land ~.:;-i~ ] ~1999 tubing. Completed operations Rigged up Tubing hanger RILDS Work completed - Tubing hanger in position Reverse circulated at 8722.0 ft Reverse circulate well to 120 deg seawater plus corrosion inhibitor. Hole displaced with Inhibited brine - 100.00 % displaced Seawater plus correxit. Set packer at 8675.0 ft with 3500.0 psi Dropped ball. Press tbg to 3500 psi to set packer, hold 30 min for tubing test. Bleed to 1000 psi. Press annulus to 3000 psi for packer test, 30 min OK. Bleed tubing pressure to shear RP. L/D landing jr. Packer set at 8675.0 ft Nipple down BOP stack Installed Hanger plug Install BPV and test to 500 psi. Eqpt. work completed, running tool retrieved Removed BOP stack N/D BOP's, removed DSA. Equipment work completed Wellhead work Installed Xmas tree N/U adapter flange and tree. Test to 5000 psi, OK. Pulled BPV. Equipment work completed Fluid system Freeze protect well - 100.000 bbl of Diesel Held PJSM. R/U lines and pumped diesel down annulus with HBR. Set BPV. Began precautionary measures Planned maintenance Facility PB DS 02 Progress Report Well 02-27A Page Rig Nabors 7ES Date 15 28 October 99 Date/Time 28 Oct 99 20:00-21:30 21:30 21:30-06:00 21:30-22:00 22:00 22:00-23:30 23:30 23:30-00:00 00:00 Duration 1-1/2 hr 8-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr Activity Serviced Block line Cut and slip drilling line while U-tube diesel. Line slipped and cut Wellhead work Tested Hanger plug Press test BPV to 500 psi. Failed. Suspended test, observed returns from wellbore Removed Hanger plug RFLI DSM lubricator and pulled BPV. No obvious defects. Equipment work completed Installed Hanger plug Installed new BPV. Tested to 500 psi, OK. Secured well and released rig. Equipment work completed Rig released 2400 hrs 10/27/99. RECEIVED 1999 An orm,. 02-27A DESCRIPTION OF WORK COMPLETED PERFORATIONS OPERATIONS Date Event Summary 11/22/1999 to 11/24/1999: MIRU work platform and CTU. PT'd BOPE. RIH w/Mem CNL logging tools and tagged PBTD at 11750' MD. Logged well f/PBTD to 11709' MD. POOH w/logging tools. RIH w/perf guns and shot 1345' of Initial Perforations at: 10140'- 10730' 10860'- 11170' 11299'- 11744' (Zone lB) Reference Log: Sperry MWD 10/21/1999. (Zone lB) (Zone lB) POOH w/guns. ASF. RD. Used 2-1/2" carriers and shot all perfs at 4 SPF, overbalanced press, 60°/120° phasing, and random orientation. Loaded wellbore w/ Crude. Placed well 02-27A on initial production and obtained a valid well test. RECEIVED 1999 ~011 & Gas C/ohs. Commieston ,~orage North Slope Alaska Alaska State Plane 4 PBU_EOA DS 02, Slot 02-27 02-27A Job No. AKMW90163, Surveyed: 24 October, 1999 ORIGINAL SURVEY REPORT 5 November, 1999 Your Ref: API-500292199401 .... Surface Coordinates: 5950809.10 N, 687554.36 E (70° 16' 13.6190" N, 148° 28' 59.0495" W) Kelly Bushing: 59.20ft above Mean Sea Level D R I L L I N I~ S ~= R V I CZ ~. S~ Survey Ref: svy9447 AHA. LLIliuR'r~N CO~APAd~r¥ Sperry-Sun Drilling Services Survey Report for 02-27A Your Ref: API-500292199401 Job No. AKMW90163, Surveyed: 24 October, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9664.59 37.100 300.870 8670.42 8729.62 9673.00 37.020 300.890 8677.13 8736.33 9695.97 39.560 300.890 8695.16 8754.36 9721.56 42.030 310.200 8714.55 8773.75 9750.16 45.920 320.490 8735.15 8794.35 9784.17 45.370 332.070 8758.97 8818.17 9812.40 44.630 340.880 8778.95 8838.15 9842.30 45.570 352.450 8800.10 8859.30 9877.38 49.700 1.060 8823.75 8882.95 9906.63 53.830 7.510 8841.86 89Ol.06 9936.63 55.410 16.120 8859.25 8918.45 9970.80 57.180 24.420 8878.24 8937.44 10009.10 64.14o 33.410 8897.02 8956.22 10034.50 70.710 37.970 8906.77 8965.97 10064.60 77.440 41.870 8915.03 8974,23 10094.10 77.180 51.740 8921.53 8980,73 10132.10 81.850 63.540 8928.46 8987.66 10162.10 89.250 69.180 8930.79 8989,99 10193.50 89.070 78.700 8931.25 8990,45 10226.30 88.930 93.400 8931.83 8991,03 10260.90 90.930 98.610 8931.87 8991,07 10292.60 90.840 105.130 8931.38 8990.58 10320.00 90.490 111.310 8931.06 8990.26 10352.20 88.090 109.530 8931.46 8990.66 10382.80 86.320 105.630 8932.95 8992.15 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 553.33 N 2993.80W 5951287.65 N 684547.70 E 555.93 N 2998.15W 5951290.15 N 684543.29 E 563.24 N 3010.36W 5951297.15 N 684530.90 E 572.96 N 3023.91W 5951306.53 N 684517.11 E 587.09 N 3037.78W 5951320.31 N 684502.89 E 607.24 N 3051.25W 5951340.12 N 684488.93 E 625.50 N 3059.21W 5951358.18 N 684480.52 E 646.05 N 3064.06W 5951378.59 N 684475.15 E 671.87 N 3065.46W 5951404.38 N 684473.11 E 694.76 N 3063.71W 5951427.30 N 684474.29 E 718.66 N 3058.69W 5951451.31 N 684478.71 E 745.28 N 3048.84W 5951478.17 N 684487.90 E 774.40 N 3032.65W 5951507.68 N 684503.35 E 793.41 N 3018.96W 5951527.04 N 684516.57 E 815.58 N 3000.39W 5951549.66 N 684534.58 E 835.26 N 2979.44W 5951569.85 N 684555.03 E 855.19 N 2947.93W 5951590.56 N 684586.04 E 867.16 N 2920.55W 5951603.22 N 684613.10 E 875.84 N 2890.42W 5951612.64 N 684643.01E 878.09 N 2857.79W 5951615.70 N 684675.58 E 874.47 N 2823.39W 5951612.94 N 684710.05 E 867.96 N 2792.39W 5951607.20 N 684741.21E 859.39 N 2766.38W 5951599.29 N 684767.42 E 848.16 N 2736.21W 5951588.81 N 684797.86 E 838.93 N 2707.08W 5951580.31 N 684827.21 E Dogleg Rate (°/100ft) 0.962 11.058 25.632 28.411 24.379 22.211 27.565 21.6o3 22.336 23.976 20.854 27.344 30.715 25.592 32.650. 32.904 3o.972 30.321 44.812 16.128 20.567 22.589 9.279 13.982 Alaska State Plane 4 PBU_EOA DS O2 Vertical Section (ft) Comment 2821.78 2826.84 2841.07 2857.72 2877.02 2899.20 2915.73 293o.87 2945.94 2956.76 2965.38 2971.38 2973.39 2972.08 2968.34 2961.25 2945.39 2928.75 2908.01 2881.71 2850.76 2821.12 2794.58 2763.10 2733.58 TIE ON SURVEY WINDOW POINT RECEIVED ?,~OV 1 8 1999 5 November, 1999 - 13:56 Alask~ Oil & Gas C, ons. ~mi~on ~chomge -2- Continued... DrillQuest Sperry-Sun Drilling Services Survey Report for 02-27A Your Ref: API-500292199401 Job No. AKMW90163, Surveyed: 24 October, 1999 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Depth Depth (ft) (ft) 10412.80 87.290 106.630 8934.62 8993.82 10444.30 88.800 105.760 8935.70 8994.90 10475.50 89.780 110.920 8936.09 8995.29 10503,30 91.170 111.780 8935.86 8995.06 10540.50 88.450 110.650 8935.98 8995.18 10572.30 87.630 108.900 8937.07 8996.27 10600.90 88.150 110.410 8938.12 8997.32 10633.10 87.970 108.370 8939.21 8998.41 10666.20 87.670 107,070 8940.47 8999.67 10693.90 88.240 104.020 8941.46 9000.66 10725.40 87,670 100.020 8942.58 9001.78 10757.40 88.700 99.940 8943.60 9002.80 10785.20 90.130 98.960 8943.88 9003.08 10827.10 91.370 97.900 8943.33 9002.53 10854.30 92,330 98.260 8942.45 9001.65 10881.60 92.070 98.480 8941.40 9000.60 10909.70 92.420 93.680 8940.30 8999.50 10944.40 93.480 93.320 8938.52 8997.72 10974.60 94.420 90.890 8936.44 8995.64 11007.20 94.270 88.740 8933.97 8993.17 11040.40 91.610 86.900 8932.26 8991.46 11067.90 87.480 86.270 8932.48 8991.68 11101.50 87.140 85.450 8934.06 8993,26 11133.40 87.490 86.140 8935.55 8994.75 11162.40 88,460 87.160 8936.58 8995,78 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 830.61 N 2678.31W 5951572.71 N 684856.19 E 821.83 N 2648.08W 5951564.69 N 684886.63 E 812.02 N 2618.47W 5951555.61N 684916.47 E 801.90 N 2592.58W 5951546.14 N 684942.60 E 788.44 N 2557.91W 5951533.55 N 684977.60 E 777.69 N 2528.00W 5951523.55 N 685007.76 E 768.07 N 2501.09W 5951514.61N 685034.91E 757.39 N 2470.73W 5951504.68 N 685065.52 E 747.32 N 2439.23W 5951495.41 N 685097.27 E 739.90 N 2412.56W 5951488.65 N 685124.11E 733.35 N 2381.78W 5951482.87 N 685155.05 E 727.81N 2350.28W 5951478.11N 685186.68 E 723.24 N 2322.86W 5951474.23 N 685214.20 E 717.10 N 2281.42W 5951469.13 N 685255.78 E 713.28 N 2254.50W 5951465.98 N 685282.79 E 709.31 N 2227.51W 5951462.68 N 685309.87 E 706.34 N 2199.60W 5951460.40 N 685337.84 E 704.22 N 2165.01W 5951459.15 N 685372.47 E 703.11N 2134.90W 5951458.79 N 685402.60 E 703.22 N 2102.40W 5951459.71N 685435.09 E 704.48 N 2069.27W 5951461.80 N 685468.18 E 706.12 N 2041.83W 5951464.12 N 685495.57 E 708.54 N 2008.35W 5951467.37 N 685528.97 E 710.88 N 1976.57W 5951470.50 N 685560.69 E 712.57 N 1947.64W 5951472.91 N 685589.57 E Dogleg Rate (°/100ft) 4.640 5.532 16.833 5.880 7.918 6.074 5.581 6.356 4.028 11.195 12.819 3.228 6.236 3.893 3.769 1.247 17.114 3.226 8.609 6.592 9.738 15,192 2.639 2.423 4.852 Alaska State Plane 4 PBU_EOA DS 02 Vertical Section (ft) Comment 2704.84 2674.63 2644.40 2617.13 2580.65 2549.66 2521.79 2490.46 2458.48 2432.01 2402.53 2372.99 2347.41 2309.17 2284.42 2259.53 2234.40 2204.09 2178.11 2150.76 2123.51 2101.25 2074.33 2048.79 2025.31 RECEIVED 5 November, 1999 - 13:56 ?iOV i 8 1999 ~lk~ 0~ & Gas Cons. C,)mmission Anchorege -3- Continued... DrillQuest Sperry-Sun Drilling Services Survey RepOrt for 02-27A Your Ref: API-500292199401 Job No. AKMW90163, Surveyed: 24 October, 1999 North. Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Depth Depth (ft) (ft) 11196.60 90.000 86.770 8937.04 8996.24 11223.40 91.110 87.380 8936.78 8995.98 11255.10 92.310 86.080 8935.83 8995,03 11287.00 92.900 82.320 8934,38 8993.58 11317.90 91.750 83.190 8933.13 8992.33 11354.10 91.630 82.930 8932.06 8991.26 11381.20 92.370 82.770 8931.12 8990.32 11411.30 91.290 83.330 8930.15 8989.35 11442.40 91.720 82.800 8929.34 8988.54 .11474.80 92.550 83.860 8928.13 8987.33 11504.10 93.450 84.060 8926,60 8985.80 11537.60 94.540 84.510 8924.26 8983.46 11566.50 93.920 84.690 8922.13 8981.33 11600.20 92.780 82.220 8920.16 8979.36 11628.90 92.950 81.160 8918.73 8977.93 11661.60 91.630 82.220 8917.42 8976.62 11692.10 91.600 81.110 8916.56 8975.76 11725.30 88.550 79.230 8916.52 8975.72 11756.90 86.960 79.050 8917.76 8976.96 11787.90 86.360 79.420 8919.56 8978.76 11808.40 87.110 78.310 8920.73 8979.93 11860.00 87.110 78.310 8923.33 8982.53 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 714.38 N 1913.49W 5951475.58 N 685623.66 E 715.75 N 1886.73W 5951477.61 N 685650.38 E 717.56 N 1855.10W 5951480.20 N 685681.96 E 720.77 N 1823.40W 5951484.21 N 685713.57 E 724.67 N 1792.77W 5951488.87 N 685744.09 E 729.04 N 1756.85W 5951494.13 N 685779.89 E 732.41 N 1729.98W 5951498.17 N 685806.67 E 736.05 N 1700.12W 5951502.56 N 685836.43 E 739.81 N 1669.26W 5951507.08 N 685867.19 E 743.57 N 1637.10W 5951511.64 N 685899.24 E 746.64 N 1608.00W 5951515.44 N 685928.25 E 749.97 N 1574.75W 5951519.60 N 685961.41 E 752.69 N 1546.06W 5951523.02 N 685990.03 E 756.52 N 1512.64W 5951527.69 N 686023.34 E 760.66 N 1484.27W 5951532.54 N 686051.59 E 765.38 N 1451.94W 5951538.07 N 686083.79 E 769.80 N 1421.78W 5951543.24 N 686113.84 E 775.47 N 1389.07W 5951549.72 N 686146.40 E 781.42 N 1358.06W 5951556.44 N 686177.25 E 787.20 N 1327.66W 5951562.97 N 686207.50 E 791.15 N 1307.58W 5951567.42 N 686227.47 E 801.59 N 1257.11W 5951579.12 N 686277.66 E Dogleg Rate (°/100ft) 4.645 4.726 5.580 11.919 4.665 0.791 2.794 4.041 2.194 4.153 3.146 3.519 2.233 8.061 3.736 5.175 3.639 10.791 5.064 2.273 6.527 0.000 Alaska State Plane 4 PBU_EOA DS O2 Vertical Section (ft) Comment 1997.49 1975.66 1949.95 1924.96 1901.23 1873.29 1852.45 1829.22 1805.22 1780.13 1757.25 1731.00 1708.27 1682.15 1660.46 1635.74 1612.68 1588.15 1565.21 1542.68 1527.87 1490.93 PROJECTED SURVEY RECEIVED I'OV i 8 1999 Continued... 5 November, 1999 - 13:56 ~ 0tl & Gas Cons, Commission Ancflorage -4- DrillQuest Sperry-Sun Drilling Services Survey Report for 02-27A Your Ref: API-500292199401 Job No. AKMW90163, Surveyed: 24 October, 1999 North Slope Alaska Alaska State Plane 4 PBU_EOA DS 02 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 302.524° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11860.00ft., The Bottom Hole Displacement is 1490.93ft., in the Direction of 302.524° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9664.59 8729.62 553.33 N 2993.80 W TIE ON SURVEY 9673.00 8736.33 555.93 N 2998.15 W WINDOW POINT 11860.00 8982.53 801.59 N 1257.11 W PROJECTED SURVEY RECEIVED 999 5 November, 1999 - 13:56 & Gas Cons. Go~m~n Anchorage -5- DrillQuest 08-Nov-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 02-27A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,664.59' MD 9,673.00' MD 11,860.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, ,~,,~~ ~"----~ William T. Allen Su~ey Manager ~_B ~chomge Attachment(s) 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 · A Halliburton Company MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson, Chairman THRU: DATE: Blair Wondzeli, P. I. Supervisor FROM: Chuck Scheve,C~ SUBJECT' Petroleum Inspector October 10, 1999 BOPE Test Nabors 7ES PBU 2-27A PTD # 99-O93 Sunday, October 10, 1999: I traveled to Arco's Drill Site 2 and witnessed the initial BOPE test on Nabors Rig 7ES drilling Well 2-27A. As the attached AOGCC BOPE Test Report indicates, the test lasted 3.5 hours and there were no failures. The testing went very well with the test procedure being practiced by the Nabors crew allowing the testing to be completed in a minimum number of steps. The rig was very clean and all equipment appeared to be in excellent condition. The location was clean and all extra equipment was properly stored. Summary' I witnessed the initial BOP test on Nabors Rig 7ES drilling Arco's 2-27A well. NABORS 7ES, 10110199, Test Time 3.5 Hours, No Failures Attachment: BOP Nabors 7ES 10-10-99 X Unclassified Confidential (Unclassified if doc. removed ) BOP Nabors 7ES 10-10-99 CS.doc STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: NABORS Rig No. 7ES PTD # SSD Rep.: 2-27A Rig Rep.: Set @ Location: Sec. Weekly Other DATE: 10/10/99 99-093 Rig Ph.# 659-4103 John Rawl Smith / Klepzig 36 T. 11N R. 14E Meridian Urn. TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted YES Well Sign OK Drl. Rig OK Hazard Sec. YES BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 250/3500 P I 250/3500 P 1 25O/35OO P 1 250/3500 P I 250/3500 P 2 250/3500 P I 250/3500 P N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250 / 3500 P 1 250/3500 P 1 250/3500 P 1 25o/3500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 25O / 35OO P 32 250 / 3500 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 @2100 2,900 P 1,550 P 0 minutes 20 sec. minutes sec. YES Remote: YES Psig. TEST RESULTS Number of Failures: 0 ,Test Time: 3.5 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good test Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve FI-021L (Rev.12/94) BOP Nabors 7ES 10-10-99 CS.xls TON Y KNO WLES, GO VEl/NOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 29. 1999 Dan Stone Senior Drilling Engineer ARCO Alaska. Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Prudhoe Bay Unit 2-27A ARCO Alaska. Inc. Permit No: 99-093 Sur Loc: 390'SNL, 818'EWL. Sec. 36. T11N. RI4E. UM Btmhole Loc. 606'NSL. 437~WEL. Sec. 26. T11N. R14E. UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson. P. E. Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC] Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. -' '-- STATE OF ALASKA --. ALASKA ..,L AND GAS CONSERVATION CON,...JlSSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork [--IDrill I~Redrill Ilb. Typeofwell I--IExploratory I--IStratigraphicTest I~Deve'lopmentOil [] Re-Entry [] DeepenI []Service [] Bevelopment Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RKB = 60.70' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028308'~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 390' SNL, 818' EWL, SEC. 36, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 402' NSL, 2082' WEL, SEC. 26, T11N, R14E, UM 02-27A At total depth 9. Approximate spud date Amount $200,000.00 606' NSL, 437' WEL, SEC. 26, T11 N, R14E, UM 10/05/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028307, 4674' MDI No Close Approach 2560 11770' MD / 8991' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9674' MD Maximum Hole Angle 91° Maximum surface 2525 psig, At total depth (TVD) 8700' / 3400 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 4-3/4" 3-1/2" 8.8# L-80 ST-L 2765' 8900' 8132' 11770' 8991' 242 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10071 feet Plugs (measured) true vertical 9061 feet Effective depth: measured 10028 feet Junk (measured) Fill at 10002' MD (09/99); Top of uppermost fish at 10056' true vertical 9025 feet MD (08/94) Casing Length Size Cemented MD TVD Structural Conductor 72' 20" 1125# Poleset 110' 110' Surface 3310' 10-3/4" 100 sx cs III, 350 sx 'a', TJ w/250 sx CS Il 3372' 3371' Intermediate Production 9234' 7-5/8" 300 sx Class 'G' 9296' 8443' Liner 1059' 5-1/2" 125 sx Class 'G' 9012' - 10071' 8222' - 9061' Perforation depth: measured (9816' _ 9820', 9828' - 9836' open straddle), 9936' - 9950', 9970' _ 10002' ("'~/~/~/ ~ true vertical (8852' - 8855', 8862' - 8868' open straddle), 8950' - 8962', 8978' - 9004' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Bill Isaacson, 564-5521 {~.~{.iS.¥~ Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~--------~""'"'""~'"~'~ Title SeniorDrillin9En~lineer Date cttl-~'/clc'l Commission Use Only Perm~ I~ m ~?)~3~1. I AP' Nurnber Approval Date - * I See cover letter "- ~ 50-029-21994~ (~ I (~%¢ ~-' ~.~,~, ~'-- ,¢",~' for other requirements Conditions of Approval: Samples Required []Yes [~No Mud Log Required []Yes r~No Hydrogen Sulfide Measures [~-Yes [] No Directional Survey Required [~Yes [] No Required Working Pressure for BOPE [-12K; J~3K; E-I4K; 1--15K; [-I 10K; [] 15K Other: ORIGINAL SIGNED. BY by order of Approved By Robert N. Christensorl Commissioner the commission Date ~) ~ "~ Form 10-401 Rev. 12-01-85 Submit In Triplicate 02-27A Permit to Drill I Well Name: 102-27A Sidetrack Plan Summary I Type of Redrill (producer or injector): I Producer Surface Location- 4889' FSL 4462' FEL S36 T11N R14E Umiat Target Location: 402' FSL 2082' FEL S26 TllN R14E Umiat Bottom Hole Location' 606' FSL 437' FEL S26 T11N R14E Umiat I AFE Number: 14J0423 I I Estimated Start Date: 110/05/99 I MD: 111,770' J I TVD: 1~99~' I I Rig: I Nabors9ES I Operating days to complete: J20 I BE/USE= 130.70' J lEKS= 160.70' I Well Design (conventional, slimhole, etc.): I Slimhole Horizontal Sidetrack I Obiective: I Development production targeting Zone 1 sands. Mud Program: Production Mud Properties: Quickdril-n 14-3/4" hole section Density (ppg) Funnel vis LSRV LSR YP pH 8.3 - 8.5 38-50 <12,000 cP 10-20 8.5-9.0 Directional: KOP: I 9674' MD Maximum Hole Angle: Close Approach Well: 91 degrees 10,642' (8999' TVD) @ None Logging Program: Production Hole(Horizontal) Drilling: Open Hole: Cased Hole: MWD / GR None Post Rig, CTU memory CNL Formation Markers: Formation Tops MD TVDss Comments Base Permafrost Not Penetrated SV3 / T5 Not Penetrated SV1 / T3 Not Penetrated UG4 / K15-C1 Not Penetrated 02-27A Permit to Drill UG1 / UgS Not Penetrated WS1 / West Sak Not Penetrated CM3 / K-12 Not Penetrated CM2 / K-10 Not Penetrated CM-1 / K5 Not Penetrated K2/Top HRZ Not Penetrated Top Kingak (JG) Not Penetrated Sag River N/A 8299' Not Penetrated Shublik N/A 8336' Not Penetrated Top Sadlerochit / Z4B N/A 8405' Not Penetrated Top Zone 4A N/A 8513' Top Zone 3 N/A 8593' Top Zone 2C N/A 8664' Kick-off Point 9674' 8677' Kick-off Point Top Zone 2B 9704' 8700' Top Zone 2A 9848' 8815' Est. Pore pressure 3400 psi (7.4 ppg EMW) Top Zone 1B 9919' 8865' CGOC 9920' 8866' Maximum TVDss 10,400' 8939' TD 11,770' 8930' Base Sadlerochit 8938' Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/I'VD 4-3/4" 3-1/2" 8.8# L-80 ST-L 2765' 8900'/8132' 1 1,770'/8991' Tubing 3-1/2" 9.3# L-80 EUE-M 9767' -33'/33' 8900'/8132' Cement Calculations: Liner Size 13-1/2" Production I Basis: Tail: Based on 90' shoe track volume, 2096' of open hole with 50% excess, 663' of 5-1/2" x 3-1/2" liner lap, 110' of 7-5/8" x 3-1/2" liner lap, and 200' of 7-5/8" x 4" drill pipe annulus volume. Tail TOC: At top of liner -8,900' MD (8132' TVD). Total Cement Volume: I Tail 50 bbl/281 ft~ / 242 sks of Dowell Premium 'G' at I 15.8 ppg and 1.16 cf/sk. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3000 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Maximum anticipated BHP: 3400 psi @ 8700' TVDss - Zone 4 Maximum surface pressure: 2525 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/E) 02-27A Permit to Drill · Planned BOP test pressure: · Planned completion fluid: 3000 psi 8.5 ppg Seawater / 6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · Drill Site 02 is not an H2S drill site. The highest level of H2S measured on DS 02 has been 10 ppm. Nevertheless, Standard Operating Procedures for H2S precautions should be followed at all times. DRILLING CLOSE APPROACH · All wells pass close approach guidelines. PRODUCTION SECTION · Differential sticking will be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time. · The kick tolerance for the kick-off point would be an infinite influx (annular volume) assuming an influx at section TD of 11,770'. This is a worst case scenario based on a 7.8 ppg pore pressure, a minimum fracture gradient of 10.0 ppg at the kick-off point, and 8.4 ppg mud in the hole. Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. SUMMARY SIDETRACK PROCEDURES Pre-Riq Work: . *Notify the field AOGCC representative with intent to~3h3~'and abandon* . , Rig up slickline. Drift tubing down through XN nipple at 9~,4' MD with 2.25" drift (this will be for upcoming chemical cuts and bridge plug). ~ Replace all live gas lift valves with dummy valves an/~id pack the 7-5/8" annulus to allow for MIT of casing. ,, ~ Test the 7-5/8 casing to 3000 psi for 30 minut,,~. , Rig up E-line. RIH with 2-7/8" Halliburton/,ic'ermanent bridge plug. Set bridge plug at 9869 MD (in middle of the 10' pup located between th¢/FB-1 packer at 9850' and 'XN' nipple at 9874'). / BP EXPLORATION ~ AOGCG ~002 are. d lces niling BP Exploration / ARCO Alaska Inc.' To: From: Subject: Reference: Blair Wondzell - AOGCC Date: September 22, 1999 William isaacson DS 02-27 Application for Sundry Permit - P&A for Sidetrack Operations APl #50-029-21994 Well 2-27 is currently shut-in and awaiting the proposed rig sidetrack. The existing completion is mechanically sound, however because of extremely high gas production, the well provides minimal benefit to the field under its current configuration. A new horizontal well is planned, which will provide standoff from gas within the reservoir and optimize production from the well. As outlined in the scope of operations below, the sidetrack kick-off point is immediately above the existing Zone 2 pedorations. Zone 1 perforations will be plugged and abandoned as part of the pre-rig work, using conventional cement placement techniques. Plans to isolate and plug Zone 2 perforations include the use of a bridge plug and the cement pumped during the new production liner cementing operations. The bridge plug will be set as part of rig operations once the existing completion has been removed. At that time the wellbore will be pressure tested to verify isolation of all perforations. Final abandonment of the perforations will be provided with the cement pumped into the 3-1/2" production liner lap (-795') above that second bridge plug. See attached diagrams for details and please call with any questions regarding the planned operations. The 2-27A sidetrack is currently scheduled for Nabors 9ES following the current sidetrack operations on W- 26A. Pre-rig work for the 2-27A sidetrack is planned to begin around September 25, 1999 and sidetrack operations are estimated to begin October 5, 1999. Pre-Riq Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. Rig up slickline. Drift tubing down through 'XN' nipple at 9874' MD with 2.25" drift (this will be for upcoming chemical cuts and bridge plug). Replace all live gas lift valves with dummy valves and fluid pack the 7-5/8" annulus to allow for MIT of casing. 2. Test the 7-5/8" casing to 3000 psi for 30 minutes. 3. Rig up CTU. Perform a cement P&A of the Zone 1 perforations with 15.8 ppg class 'G' cement, using aggregate as required to aid in plugging perforations. Use adequate cement volume to fill the 5-1/2" liner from the top of fill/junk at 10,002' MD to the tubing tail at 9881' MD, and fill the 2-7/8" tubing to a maximum depth of 9840' MD (60' below planned cut depth), plus squeeze a minimum of 5 bbls into the perforations. Estimated minimum cement volume needed is 8 barrels. 4. Rig up E-line. Chemical cut the 2-7/8" L-80 tubing at 9780' MD (this is within the second full joint of tubing above the Blast Ring joint at 9829' MD). Do Not cut tubing any shallower than 9780'. This cut will not be fished and does not need to be in the center of the Joint. Chemical cut the 3-1/2" L-80 tubing at 8787' MD (this is -3' down into the 10' pup immediately below the 'SB-3A' packer). This cut will be fished and placement of the cut is Critical, As planned, the specified cut depth will leave a 7' stub for fishing the remaining equipment from the well. RIH and perforate the 3-1/2" tubing at 8750' MD (this is in the middle of the 10' pup immediately above the 'SB-3A' packer). 5. Dispiace the well to clean seawater through the tubing perforations at 8750' MD and freeze protect the top 2200' MD with diesel. 6. Test the McEvoy 7-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. 7. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger. Secure well. 8. Remove the well house and flowlines, if necessary, level the pad. Please provide total well preparation cost on the handover form. Riq ODerations: 1. MIRU Nabors 9ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC, 4. Pull and lay down 4-1/2" x 3-1/2" completion from upper production packer at 8755' MD, 5. Make-up packer mill. RIH and mill 7-5/8" packer. POOH 6. RIH with spear and fish 7-5/8" packer down to top tubing cut at 8787'. POOH. 7, RIH with overshot and recover completion equipment down to lower tubing cut at 9780'. POOH. 8. RU E-line and make GR/JB run to top of tubing cut. MU bridge plug. RIH and set at 9695'. 9. RIH with 5-1/2" Baker whipstock assembly. Orient whipstock as desired and set on bridge plug. Mill window in 5-1/2" casing at 9674' MD. POOH. 10. Kick-off and drill the 4-3/4" production interval, building at -2701100, to horizontal, targeting the Zone 1 sands. Drill ahead to an estimated total depth of 11,770' MD (8991' TVD). 11. Run and cement a 3-1/2", 9.3# solid production liner throughout the 4-3/4" wellbore and back into the 5- 1/2" and 7-5/8" casing to the liner top at -8900'. 12. Test the 3-1/2' and 7-5/8" casing from the 3-1/2" landing collar to surface to 3000 psi for 30 minutes. Displace well to clean seawater above liner top. POOH LD DP. 13. Run 3-1/2", 9.3# L-80 completion tying into the 3-1/2" liner top. 14. Set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 15. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 16. Freeze protect the well to -2200' and secure the well. 17. Rig down and move off. Post-Rig Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below the production packer and install gas lift valves. 2. MIRU CTU. Run memory CNL over reservoir section. Perforate -1000' of Zone 1. Estimated Pre-rig Start Date: Estimated Spud Date: 09/25/99 10/O5/99 William Isaacson Operations Drilling Engineer 564-5521 09/22/99 12:44 FAX 907 564 5193 BP EXPLORATION ~ AOGCC ~ 004 C ~Jrt~ ~-- T~ ~-r 6938' Min IO-2.750 Otis XN -'_Nj p_wn'r PLUG Tubing-PC XO PKR Perf FISH ToP FISH 02-27 02-27 APl: ~0292199400 H25: SSSV Ty~e: Reference Log: BHC8 . Well TYPe:. PROD Spud: 12/18189 Grig Cemp~n: 3/30/90 Lad W/O: 2/21/90 Ref Log Dele: lf9/gO Last Tag:. Last Tag DMe: Rev Re.on: GLV upd-Ma La~ Update: 10112/98 Depth',Annolatl~i~. '. ' '..'.': '. '. ".'..'::. ' - ' Depth Comment (ftKe) ElevaUons :: " ,::',:. ':" ' ' KB 63 It Cae Flng 0 It <:;rd 31 It Tub Head 0 It KG-C-rd 32 fl OtherLalug~, .equip., etc,)-;AIl.' - '" -:;:.,:' ' Depth ID Type Description 2203 3.81 TRSSSV 4-1/2" AVA TRSV $ S 8V hqpple 3093 0,00 XO Cro~over 4.11Z" x 3-1f2" 8755 O,~0 PKR 7-S/~ x 3-1/2' Baker 8B-3A Packer 8936 2.75 NOGO 3-1/2' ot~ XN Nipple wtTT PLUG 8951 0.00 XO Cro~ove~ 3-1/2" x 2-718" 98S0 0.00 PKR ~'-.I/'['~x 2-7/8" Bd:e~ FB PeCker 9874 ?_25 HOGO 2-7/8" Otis XN Nipp~ 9880 0.0~ SOSUB 2-7/8" Baker Sh-_.am~ Sub 98111 0.00 TI'L 2-7/8'* Tubing Tall General Notes : Date Note 3r30/;0 Trt. ELM ~ 987e: ELM TT(Logged 08/13/90) 8938 MIn ID = 2.750" (3-1/2" Otis XN Nipple) FRAC 06/01/90 BALL SEALER TREATMENT 06/01/90 No~ Ar~c pa~ed Fish - FISH Depth Description Comment 10056 FISH 1-1/2" DGV (Lost 07/21/90) 10061 FISH TGE Prong) 10066 FISH 6" Long CTU No,,le & Che~ Casing Strings -.All · Size De~cflpflon Top Btm Weight 7.63 Cooing 0 4440 29.70 7.63 Caeit~ 4400 9296 29.70 6.50 Uner 0011 10070 17.00 10.75 Casing 0 3405 46.60 Tubing $tflng~ - All Size Oescripti0n Top Btm Weight 4.50 Tubing.PC 0 3093 12.50 3.50 Tubing. PC 3093 8961 9.30 2.88 Tubing. PC 8951 9881 6.60 Chemical MandrelsNatves RKB: 63 fl KOP: 0.00 ft~B PBT~. 10O71.0O ftK~ TO: 10071.00 fAB Max Hole Angle: 40 deg O g300 An~a ~ TS: 40 ck~ ~ 9328 Angle (~ TD: ~$ dog ~ 10071 Date 7/21/90 8/19/94 8/8/g0 Grade L-80 L-80 L-SO J-65 Grade L-80 L-80 L--80 $tn MD Man Man Type VIv Vtv Vlv Latch VIv Vlv Vlv Run Vlv Mfr Mfr OD Type Port TRO , Comment (In) 8 8665 CA CA 1.50 RCI-2 TC~ 0.19 3340 8120~J4 Gas Lift MandrelsP(elve$ Stn MD Man Man Type VIv VIv VIv Latch Vlv Vlv Vlv Run Vlv Mfr Mfr OD Type Port TRO Comment (In) 1 'H98 TE TGPD TE 1.50 N-15R TO 0.25 1700 Z/21/90 2 49~6 TE TGPD TE 1.50 O-20R TG 0.38 2/21/90Piece TGE behind 3 6320 TE TGPO TE 1.50 D-14R TG 0.00 2/21/90 4 7184 'rE TGPO TE 1.60 D-14R TG 0.00 8/20/94 5 7646 TE TGP~ TE 1.50 D-14R TO 0.00 2/21/90 6 7895 TE TGPO TE 1,50 D-14R TG 0 O0 2/21/90 7 8512 TE TQPD CA 1.50 RKED RK 0.00 Z~2 !/90 Production Mandrels/Valves Stn MD Man Man Type Vlv VIv Vlv Latch VIv Vlv Vlv Rte Vlv Mfr Mfr OD Type Port TRO Comment (In) 9 8794 TE TGPD TE 1.50 DMY TG 0.00 2/21/9o 10 88~6 TE TGPD CA 1.50 OV TG 0.25 8/20'94 Unable lo pull O6/28/97 Perforallons Summary Interval Zone Statu., Feet SPF Date Type Comment 9816.- 9620 ZONE2 O 4 3 2/18/90 IPERF 9828 * g$36 ZONE 2 O 8 3 2/18/90 IPERF 9936 - 9950 ZONE 18 0 14 112 2/18/90 IPERF 9970-10002 ZONE lB,HOTO 32 4 2/18/90 IPERF i i i i i i i i i ' · 2-27A Proposed Completion WELLHEAD: 11" - 5M FMC Gert IV SH'I'B Cellar Elevation = 30.7" Nabors 9ES RKB = 60.70' 3-1/2' 'X' Landing Nipple with 2.813~ seal bore. 10-3/4', 45.5 #/ft, J-55, BTC I' 3372' , I 3-112" x 1-1/2' Camco 'MMG' Gas Lift Mandrels with handling pups Installed above and below. GAS UFT MANDRELS Size I TBD 1-112" TBD 1-1/2' TBD 1-112' TBD 1-1/2' Valve Type RP She~r DV DV DV 3-1/2" 9.3# L-80, EUE 8rd. Mod Tubing 7-5/8" Baker '$-3' Production Packer crossed over to 3-1/2'. 3-1/'2' 'X' Landing Nipple with 2.813" seal bore. 3-I/2" WireLine Ent]7 Guide spaced-out into liner top. 5-1/2' Liner Top at ~ I +/-.BgO0' I BAKER 5-1/2' x 7-5J8' i Tie Back Sleeve ZXP Liner Too Packer 'HMC' Hydraulic Error Hanger 7-5/8", 29.7 #/ft, L.80, BTC ~ Cement in Liner lap from Bridge Plug to Uner Top at +1-8900' MD Window Milled froro Whipstock Top of Window at +/-9674' MD Bridge Plug set at +/-9695' MD Zone 2 Perfs Horizanlal Sidetrack into Zone 1 Sands 3-~/~' 9.3 #,~ L-~o. sT.L Plug Back Depth Cement Plug lo P&A Zone I Perfs Zof~e 1 Perfs 5-112", 17 #/ft, L-80, FL-4S I: 10,~'1' J Date Rev By Comments PRUDHOE BAY UNIT 9='z~9 w, sl ,P.:~o~ co~, WELL: 2-27A APl NO: 50-029-21994-01 , Shared Services Drilling i I II I Il I I Ill Horizontal Coordinates; Ret. Global Coordinates: 5950809.10 N, 687554.36 E Re/, Shucturo Reference : 2010,85 N, 35,78 W Roi. Googrephical Coordlnah)s: 70" 16' 13.6190' N, 148" 28' 59.0495" W RKB EluvlltlOll: 60.'/Oft abow) Mi)aR Su¢l Lovnl 60.70ft above ShtlCttlll¢ ROtUIdI1CO NorU1 Rub)fence: TrLIO North _Un ts: Feet Shared Services Drilling 02 27A W p9 02-27A Wp9 Measurement Units: ft Target TVDrkb TVDss Local Local Global Global Target Name Northings Eastings Northings Eastings Shape 2-27A 6-Scp-99 lnt A8998.70 8938.00 843.92 N 2719.17 W 5951585.00 N684815.00 E Point 2-27A 6-Scp-99 Iht B8998.70 8938.00 850.00 N 2373.91 W 5951599.68 N685160.01 E Point 2-27A 6-Scp-99 Iht C8993.70 8933.00 850,00 N 2084.00 W 5951606.90 N685449,83 E Point 2-27A 6-Scp-99 Land 8987.70 8927.00 793.42 N 2900.49 W 5951530.00 N684635.00 E Point 2-27A 6-Scp-99 TD 8990,70 8930.00 997,48 N 1254.89 W 5951775.00 N686275.00 E Point DrillQuesf Proposal Data for 02-27A Wp9 Vedical Origin: Well Horizontal Origin: Well Measurement Units: ft North Relerence: True North ~);glog S~vorit-'~'~ ..... Degree--; p-~r]-O~]i Verlical Section Azimutl]: 75.800" Vertical Section Description: Well Vertical Section Origin: 0.00 N,0.00 Measured Incl. Azim. Vertical Northing$ Eastlngs Vertical Dogleg Depth Depth Section Rate 9674.00 37.026300.890 8737.43 555.79 N 9704.00 39.841304.502 8760.93 565.87 N 10102.3089.8611 65.791 8987.70 793.42 N 10210.5685.135:: 77.9088992.44 827.06 N 10267.4885.135; 77.908 8997.27 838.94 N 10291.3688.000:78.000 8998.70 843.92 N 10402.1390,377:: 91;080 9000,28 854.43 N 10632.19:90377 9i.080 8998.76 850. l0 N 10637.4391J)00 91:1000 8998.70 850.00 N 111642,26:91.1155: 90.423 8998.61 849.94 N 10881.71 91.055:91k423 8994.20 848.17 N 10927.4590;204 85,000 8993.70 850.00 N 10970.9590.204 79.779 8993.54 855.76 N 11769;6390.204 79.779 8990.70 997.48 N 2997.89 W -2769.95 3013.56 W -2782.6712.000 29(×).49 W-2617.2327.447 2797.94 W -2509.5712,000 2742.48 W -2452.890.000 2719.17 W -2429.0712,('X)() 2609.16 W -2319,8412.000 2379.14 W -2097.920.000 237331 W -2092.8612.000 2369.118 W-2088.2012.111111 2129.68 W -1856.550.0tX) 2084.011W .1811.8112.000 2040.89 W -1768.6112.000 1254.89 W -971.86 0.tX)0 8700 - oo (11 II )' .= 9000 - o ._ ............ ,~i~;:/':"~."'¢0¢~ ............................................... :::'.' ~oae© ............ '~ ...... ~'xg~*~ ....... :'.~' '~ ................................ ~e'::,.~>~:~6 ................ 7' :~' : .................................................... wO° t~ ou~ ................ Y x~ :~Txt- ~.~. ~. .~ ........ :' ~-<xt ~[(~-v .................................. ~' : azi,.'% ...... ':'T.'~¥. .' 2'. '. 2 ~ ............ UU ....... ~-~a ~r .'..:~ ~ .3 ~: ...~xX. = A g.~ ..... ~ .~. .X O* .... ..=~ ¢)~.~. : ....................................................................................... ('(;0(' . .s'u2r,. 7o 'rvi, ,' ~ / / / SLa LO 5~, ~6 / , o2-27a Wp9 ....... /' ........ ~,~ /, ........ ~ ~,,~ . ),~'~,/~ =...( .... :'.'~% ...........,.,.:'%?~ ........... '.'~% ........... '.'?).% ..... , ............................... / ~~._ ..... ~ ~ ~ ~ fl3~D - ,Wg,~'. ~o TVD ' 27 t 6 %'tF 99 Ixt,td '7 t 6 5' ' in A 2 A 6 "It t B ' 27 6 e 99 nt ~ 2 .... " ~ ~ , ,' ~ - 2-2 ~ ,-, ep-99 t -27 ,-Sep-99I z- A ~-S p- I C ~ 4 m, o~ ~ 2-27A 6-Sep-99 TD '"""'/~ < ' - 8998.70 TVD 8998.70 TVD 8993.70 TVD /~ 793.42 N, 2900.49 W 843.92 N, 2719.17 W 850.00 ~ 2373.91 W 850.00 N, 2084.00 W Total Depth ' 8990.70 TVD ,~/ 997.48 N, 1254.89 W ,'~' 11769.63ff MD, / 8990.70~ ~D I I I r I I I -2700 -2400 -2100 -1800 -1500 -1200 -900 Scale: 1 inch = 300ft Vertical Section Section Azimuth: 75.800° (True North) , , ssPar"r" J-ssur31 Shared Services Drilling I DrillQuest'" 02-27A Wp9 0_2-27A W_p9 Well: 02-27A WPS Proposal Data for 02-27A Wp9 Horizontal Coordinates: Ref. Global Coordinates: 5950809.10 N, 687554,36 E Ref, Stlucture Reference : 2010,85 N, 35,78 W Vedical Origin; Well Rot, Geographical Coordinales: 70" 16' 13,6190" N, 148" 28' 59,0495" W Horizontal Origin: Well Measurement Units: fl RKI3 Elr~w~tion: 60.70ft60'70ft abovoab°v° MOanStmCtLlreSOaReferenceLevel ~ Reference: True Nodh Dogleg severity: Degrees per 100fi Vedica) Section ~imuth: 75.800° Nodh Referellce: True Nodh Units: Feet Vedical Section Description: Well Ve~ical Section Origin: 0.00 N,0.00 E Measur~ Incl. Azlm, Veffical Nodhings Eastings Ve~lcal Dogleg i 02-27A Wp9 Depth Depth Section Rate 9674.00 37.026 300,~90 8737.43 555,79 N 2997.89 W -2769,95 Measurement Units: ft 9704,00 39,841 3(H,502 8760.93 565.87 N 3013,56 W -2782.67 12.0(X) 10102,30 89.860 65.791 898?.?0 793.42 N 2900.49 W -2617.23 27.~7 10210,56 85.135 77,908 8992,~ 827.06 N 2797,94 W -2509,57 12.000 Target TVDrkb TVDss Local Local Global Global Target 10267,48 85.135 : 77.908 8997.27 838,94 N 2742.48 W .2452.89 0,000 Name Northings Eastings Northings Eastings Shape 10291.36 : 88 000 ::: :~8 000 8998,70 843,92 N 2719.17 W -2429.0? 12,000 I~02,13 90;377 91080 9000,28 854,43 N 2609.16 W -2319,84 12.000 I 10632.19 90~377 91.080 8998.76 850,10 N 2379.14 W -2097,92 0.0(X) 2-27A 6-Scp-99 Iht A 8998.70 8938.00 843.92 N 2719.17 W 5951585.00 N 684815,00 E Point 10637.43 91.000 91.000 8998.70 850,00 N 2373.91 W -2092.86 12,000 10(~2,26 :::91.055 90.423 8998.61 849,94 N 2369.08 W -2088,20 12.0(~ 2-27A 6-Scp-99 Iht B 8998.70 8938.00 850.00 N 2373.91 W 5951599.68 N 685160,01 E Point 10881'~7i: ':9i.05590,423 8994.20 848.17 N 2129.68 W -1856.55 0.000 1092745: 90.2(~ 85.(~)0 8993.70 850,00 N 2084,00 W -1811,81 12,000 2-27A 6-Scp-99 Iht C 8993.70 8933.00 850.00 N 2084,00 W 5951606.90 N 685449.83 E Point 10970,95 ' 90.2~ 79.779 8993.54 855,76 N 2(~0.89 W -1768.61 12,(XX) 11769:63 90,2(~ 79.779 8990.70 997,48 N 1254.89 W -971.86 0.000 2-27A 6-Scp-99 Land 8987.70 8927.00 793.42 N 2900.49 W 5951530.00 N 684635,00 E Point 2-27A 6-Scp-99 TD 8990.70 8930.00 997.48 N 1254.89 W 5951775.00 N 686275,00 E Peint ........ .,~q° Eastings -3000 -2750 -2500 -2250s~..~13Ox' -2000: x1750 -15~ -1250 Scale: 1 inch = 250ft . he,oil_a91 gq* ~agS~ ~O~.> ._~ ~ ~ 2'27A 6-Sep,99 Iht A 2-27A 6-Sep-99 iht B 2-27A 6-Sep-99 Iht C ~ I ~ i ~ ~ 8998.70 TVD 8998.70 TVD 8993.70 TVD ~~ / ' ' 843.92 N, 2719.17 W 8~0 O0 N 2~7~ 91 W 850.00 N, 2084.00 W ~ '-- 750 ~ 750 0 ~ 2-27A 6-Sep-99 Land~ Z I / 8~87.70 TVO ~ 793.42 N, 2900.49 W O m % [ Staa Dir ~ 27.447°/100ft: 9704.00 . H ~¢~ KOP~op Whipstock: Staa Dir ~ 12°/100ft: 9674.00ft MD, 8737.43ft TVD · ~ 500 -- ~ ........ 500 -3000 -2750 -2500 -2250 -2000 -1750 -1500 -1250 Scale: 1 inch = 250ft Pastians Reference is True No~h Sperry-Sun Drilling Services Proposal Report for 02-27A WPS - 02-27A Wp9 Prudhoe Bay Unit Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 9674.00 37.026 300.890 8676.73 9700.00 39.459 304.046 8697.15 9703.69 39.812 304.467 8700.00 9704.00 39.841 304.502 8700.23 9800.00 36.032 347.600 8777.27 9847.72 40.039 7.931 8815.00 9900.00 47.714 25.515 8852.80 9918.74 51.025 30.702 8865.00 9920.33 51.317 31.121 8866.00 10000.00 67.324 48.578 8906.75 10100.00 89.346 65.425 8926.98 10102.30 89.860 65.791 8927.00 10200.00 85.590 76.721 8930.89 10210.56 85.135 77.908 8931.74 10267.48 85.135 77.908 8936.57 10291.36 88.000 78.000 8938.00 10300.00 88.183 79.021 8938.29 10400.00 90.331 90.829 8939.59 10402.13 90.377 91.080 8939.58 10500.00 90.377 91.080 8938.93 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings (ft) (ft) (ft) (ft) 8737.43 555.79 N 2997.89 W 5951290.01:N~: 8757.85 564.43 N 3011.45 W 5951298131 N 8760.70 565.76 N 3013.40 W 5951299:59 N 8760.93 565.87 N 3013.56 W 5951299.70 N 8837.97 611.68 N 3045.53 W 5951344.69 N 8875.70 640.72 N 3046.43 W 5951373.70 N 8913.50 675.00 N 3035:73 W 5951408.24 N 8925.70 687.53 N 3029.02 W 5951420.93 N 8926.70 688.59 N 3028.38 W 5951422.01 N 8967.45 740.16 N 2984.21 W 5951474.66 N 8987.68 792.48 N 2902.58 W 5951529.00 N 8987.70 793.42 N 2900.49 W 5951530.00 N 8991.59 824.75 N 2808.21W 5951563.62 8992.44 827.06 N 2797.94W 5951566.18 8997.27 838.94 N 2742.48W 5951579.44 8998.70 843.92 N 2719.17W 5951585.00 8998.99 845.64 N 2710.71W 5951586.93 9000.29 854.47 N 2611.29W 5951598.23 9000.28 854.43 N 2609.16W 5951598.25 8999.63 852.59 N 2511.31W 5951598.84 Alaska State Plane Zone 4 PBU_EOA DS 02 Dogleg Vertical Eastings Rate Section :(ft) (°/100ft) (ft) :684543.56 E -2769.95 684529.78 E 12.000 -2780.98 684527.80 E 12.000 -2782.54 684527.63 E 12.000 -2782.67 684494.53 E 27.447 -2802.43 684492.91 E 27.447 -2796.18 684502.75 E 27.447 -2777.39 684509.15 E 27.447 -2767.81 684509.76 E 27.447 -2766.93 684552.63 E 27.447 -2711.46 684632.93 E 27.447 -2619.49 684635.00 E 27.447 -2617.23 N 684726.47 E 12.000 N 684736.68 E 12.000 N 684791.82 E 0.000 N 684815.00 E 12.000 N 684823.42 E 12.000 N 684922.58 E 12.000 N 684924.71E 12.000 N 685022.58 E 0.000 -2520.09 -2509.57 -2452.89 -2429.07 -2420.45 -2321.90 -2319.84 -2225.44 Comment KOP/Top Whipstock: Start Dir @ 12°/100ft: 9674.00ft MD, 8737.43ft TVD Z2B Start Dir @ 27.447°/100ft · 9704.00ft MD, 8760.93ft TVD Z2A Z1B CGOC Dir Rate Decrease (soft land)@ 12.000°/100ft: 10102.30ft MD 8987.70ft TVD Taraet - 2-27A ~~Sep-99 Land Geo'logical ' End Dir: 10210.56ft MD, 8992.44ft TVD Start Dir @ 12.000°/100ft: 10267.48ft MD, 8997.27ft TVD Tarqet - 2-27A 6-Sep-99 Int A, Geological End Dir' 10402.13ft MD, 9000.28ft TVD Continued... 10 September, 1999 - 15:20 - I - Dr#/Quest Sperry-Sun Drilling Services Proposal Report for 02-27A WPS - 02-27A Wp9 Prudhoe Bay Unit Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 10600.00 90.377 91.080 8938.27 10632.19 90.377 91.080 8938.06 10637.43 91.000 91.000 8938.00 10642.26 91.055 90.423 8937.91 10700.00 91.055 90.423 8936.85 10800.00 91.055 90.423 8935.01 10881.71 91.055 90.423 8933.50 10900.00 90.716 88.254 8933.22 10927.45 90.204 85.000 8933.00 10970.95 90.204 79.779 8932.84 11000.00 90.204 79.779 8932.74 11100.00 90.204 79.779 8932.39 11200.00 90.204 79.779 8932.03 11300.00 90.204 79.779 8931.67 11400.00 90.204 79.779 8931.32 11500.00 90.204 79.779 8930.96 11600.00 90.204 79.779 8930.60 11700.00 90.204 79.779 8930.25 11769.63 90.204 79.779 8930.00 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8998.97 850.70 N 2411.33 W 5951599.45 N ~ :685122.58 E : 8998.76 850.10 N 2379.14 W 595~599164:N 685154.77 E 8998.70 850.00 N 2373.91 W 5951599i68 N 685160.01 E 8998.61 849.94 N 2369.08 W 595~599.74 N 685164.84 E 8997.55 849.51 N 2311.35 W 5951600.75 N 685222.55 E 8995.71 848.78 N 2211.37 W 5951602.51 N 685322.52 E 8994.20 848.17 N 2129.68 W 5951603.94 N 685404.20 E 8993.92 848.39 N 2111.39 W 5951604.61 N 685422.48 E 8993.70 850.00 N 2084.00 W 5951606.90 N 685449.83 E 8993.54 855.76 N 2040.89 W 5951613.74 N 685492.78 E 8993.44 860.91 N 2012.31W 5951619.60 N 685521.23 E 8993.09 878.66 N 1913.89W 5951639.79 N 685619.17 E 8992.73 896.40 N 1815.48W 5951659.98 N 685717.11 E 8992.37 914.15 N 1717.07W 5951680.18 N 685815.04 E 8992.02 931.89 N 1618.66W 5951700.37 N 685912.98 E 8991.66 949.64 N 1520.24W 5951720.56 N 686010.92 E 8991.30 967.38 N 1421.83W 5951740.75 N 686108.86 E 8990.95 985.13 N 1323.42W 5951760.94 N 686206.80 E 8990.70 997.48 N 1254.89W 5951775.00 N 686275.00 E Alaska State Plane Zone 4 PBU_EOA DS 02 Dogleg Rate (°/100fi) 0.o00 o.ooo 12.0o0 12.oo0 0.0oo o.0oo o.o0o 12.0o0 12.0o0 12.000 0,000 0,000 0.000 0,000 0,000 0.000 0.000 0.000 0.000 Vertical Section Comment (ft) -2128.97 -2097.92 Start Dir @ 12°/100ft: 10632.19ft MD, 8998.76ft TVD -2092.86 Tamet- 2-27A 6-Sep-99 Iht B, Geo'log!cal -2088.20 End Dir: 10642.26ft MD, 8998.61ft TVD -2032.34 -1935.59 -1856.55 Start Dir @ 12.000°/100ft: 10881.71ft MD, 8994.20ft TVD -1838.77 -1811.81 T_.ar[let .- 2;27A 6-Sep-99 Iht C, ~eologlcal -1768.61 End [:)ir: 10970.95ft MD, 8993.54ft TVD -1739.63 -1639.87 -1540.12 -1440.36 -1340.60 -1240.84 -1141.08 -1041.32 -971.86 Total Depth: 11769.63ft MD, 8990.70ft TVD 3 1/2" Liner Taraet - 2-27A 6-Sep-99 TD, Geological Cont/nued... 10 September, 1999 - 15:20 - 2 - DrillQuest WELL PERMIT CHECKLIST FIELD & POOL ~ ~ 0 1~ ADMINISTRATION 1. 2. 3. Ur )PR DATE ENGINEERING APPR DATE 4. W~ 5. W, 6. W, 7. Su 8. If 9. O 10. O 11. Pe 12. Pc 13. CI 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. C( Ad~ Ifa Ad~ Ifd Dril BO BO Ch(' Wol ~s p~ GEOLOGY DATE 30. 31. 32. 33. 34. Pen Dati Sell Co ANNULAR DISPOSAL APPR DATE 35. Witt (A)~ (B)] (c)~ (D) ~ I (E)~ GEOL~,~I DATE I CHECK NO. J H 155825 08/30/9 I 00:!.55825J VENDOR ALASI4AST ! 4 CO ,, DATE INVOICE / CREDIT MEMO DESCRIPTION GROss DISCOUNT NET ,, 082799 CK0827998 100. CO 100. CO HANDLING INST' S/H TERRI HUBBLE X46;28 ,, rile A~ACHED CHECK IS IN PAYMEm FOR ~MS DE~RIBED AaOVE. ~ 100. O0 100. O0 H ::.: BP.EXPLORATION (ALASKA),:.INC, ::::' I : i.:. !: .'~;.0.:BOX'1196612 i':'.::.":::?~:.;: ~ ,:: .. : ::: ., :.' . ,;::: ; ,. 'ANCHORAG'E~ ALASKA'. 99519-6612 ..: '~ "~: 'FiRsT NATIoNAL.BANK ;OF ASH~.AND ..... 'CLEvELanD, O'HiO · ,.;: *. · ' ~:':;: ': ~: 56:389 412 No., ::H 55825. CONSOLIDA rED cOMMERcIAL:ACCOUNT· O01558;25:': PAY TO The ORDER" .. DATE ALASKA STATE ,DEPT OF REVENUE ' 3001.:::PORCUPINE':DR :' : .:..:: .~: . uS:' DOLLAR AMOUNT $100. O0 NOT V.~!71D AFTER 120 DAYS : ANCHORAGE AK 99501-3120 c:\msoffice\wordian\diana\checklisl Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX, No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Apr 13 11:48:49 2000 Reel Header Service name ............. LISTPE Date ..................... 00/04/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/04/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROLrND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MW- 90163 E. CRIBBS G. KIDD DS 2-27A 500292199401 ARCO Alaska, inc. Sperry Sun 13-APR-00 MWD RUN 3 AK-MW- 90163 E. CRIBBS G. KIDD 36 lin 14E 390 MWD RUN 4 AK-MW- 90163 R. KRELL G. KIDD 818 .00 59.20 30.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.750 5.500 9673.0 4.750 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING APR 24 2OOO Ala~ka Oil &Gas Cells ..... ,,,,",ssior~ Anchorage R]~MARKS: 1. ALL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED IN THE WELL INFORMATION. 3. MWD RUNS 2 THRU 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 4. DIGITAL AND LOG MWD DATA ARE DEPTH-CORRECTED TO THE PDC GR LOG OF 11/22/99 WITH KBE = 62.0' A.M.S.L.. THIS WELL KICKS OFF FROM 02-27 AT 9673'MD, 8736'TVD. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 1-4 REPRESENT WELL 2-27A WITH API # 50-029-21994-01. THIS REACHED A TOTAL DEPTH OF l1860'MD, 8983'TVD. SGRC = SMOOTHED GAMMA RAY COMBINED SROP = SMOOTHED RATE OF PENETRATION $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NIIMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9673.0 11819.5 ROP 9701.0 11860.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9673.0 9698.0 9707.5 9711.5 9715.0 9728.5 9730.0 9733.5 9740.0 9745.0 9749.5 9753.5 9757.5 9772.0 9775.5 GR 9670.5 9695.5 9705.0 9709.0 9711.5 9725 5 9728 0 9736 5 9739 0 9743 5 9748 0 9751 0 9757 5 9772 0 9774 5 EQUIVALENT UNSHIFTED DEPTH APR 24 2000 Oil & Gas u,:,n~. Oommi~ion ~ohomge 9778.5 9798.5 9800.5 9804 0 9811 5 9812 5 9831 0 9836 0 9837 0 9843 0 9863 0 9867 5 9871 0 9876 5 9878 5 9883 5 9893 0 9900 5 9912 0 9918 0 9920 0 9924.5 9932 0 9936 0 9958 5 9965 0 9978 0 9982 0 9987 0 10011 0 10021 5 10026 0 10031 0 10033 5 10035 5 10057.0 10061.0 10064.5 10067.0 10069.5 10072.0 10084.0 10087.0 10113.0 10130.0 10140.0 10163.0 10165 5 10174 5 10188 5 10206 5 10211 5 10214 5 10219 0 10223 0 10226 5 10267 0 10274 0 10278 5 10284 5 10287 0 10292 0 10294 0 10304 0 10306 5 10313 0 10315 5 10318 0 9777.5 9796.0 9799.0 9804 5 9810 5 9811 5 9826 5 9831 5 9834 5 9841 5 9861 5 9865.5 9871 0 9875 0 9877 5 9882 5 9891 5 9900 0 9911 0 9917 5 9920 5 9923 0 9931 5 9934 5 9958.5 9964 0 9977 5 9982 5 9986 0 10010 5 10020 0 10024 5 10031 0 10033 0 10036 0 10057 5 10059.5 10065.0 10067.0 10070.0 10071.5 10084.5 10087.5 10111.5 10129 5 10140 0 10162 0 10165 0 10174 5 10188 0 10206 0 10210 5 10213 5 10218 5 10221 0 10225 0 10267 5 10275 5 10279 0 10283 5 10285.5 10290 5 10293 0 10303 0 10307 5 10313 5 10316 0 10317 5 ' 10319.5 10326.5 10329.0 10331.5 10332.5 10335.5 10336.5 10341.5 10343.0 10346.5 10349.5 10352.5 10354.0 10358.5 10361.5 10363.0 10364.5 10366.0 10371.5 10375.0 10381.5 10385.5 10387.5 10389.5 10395.0 10399 0 10427 5 10432 5 10437 5 10443 0 10447 5 10451 0 10458 0 10460.0 10464.0 104 71.0 10482.5 10518.0 10520.0 10524.0 10541.5 10544.5 10549.0 10553.5 10556.0 10559.5 10562.0 10568.0 10571.5 10573.0 10575.0 10577.0 10580.5 10590.5 10593.5 10598.0 10600.5 10634.5 10636.5 10641.5 10646.5 10649.0 10662.0 10664.5 10668.0 10671.0 10675.0 10681.5 10318.5 10325.0 10326.0 10332.5 10334.0 10337.0 10338.5 10342.5 10344.5 10348.0 10349.0 10351.0 10352.5 10356.5 10358.5 10361.5 10364.0 10365 0 10370 5 103 73 5 10380 0 10384 5 10387 0 10391 0 10399 0 10400.5 10430.0 10434.0 10439.5 10443.5 10448.5 10452.5 10461.0 10463.5 10466.5 10473.0 10483.5 10518.0 10519.5 10523.0 10542.0 10545.5 10550.5 10554.5 10558.0 10561.0 10563.0 10569.0 10572.0 10573.5 10574.5 10576.5 10579.0 10590.0 10594.0 10598.5 10600.5 10633.5 10636.0 10640.5 10645.0 10648.5 10663.0 10665.0 10667.5 10672.0 10676.0 10681.0 , , aPR 24 2000 Anchorage 10683 10688 10691 10700 10704 10708 10710 10715 10719 10727 10734 10738 10748 10751 10769 10778 10779 10782 10786 10788 10790 10796 10808 10811 10814 10822 10828 10830 10842 10848 10851 10858 10873 10881 10889 10908 10909 10912 10914 10916 10918 10924 10934 10938 10949 10962 10973 10975 10986 11012 11016 11020 11036 11039 11045 11069 11072 11073 11075 11077 11082 11159 11175 11181 11188 11197 11201 11209 .0 .0 .5 .5 5 0 5 5 5 0 0 0 0 5 0 0 5 0 0 5 0 0 5 5 5 5 0 0 0 0 5 0 5 0 5 0 5 5 5 0 0 0 5 5 5 0 0 0 0 5 0 0 5 0 0 0 0 0 0 0 0 5 0 5 5 0 0 0 10683 0 10687 5 10691 5 10699 5 10703 0 10706 0 10709 0 10713 5 10718 5 10728 0 10735 5 10740 0 10748.5 10751.0 10768.5 10779.5 10782.0 10784.0 10787.0 10789.5 10791.5 10798.0 10809.5 10813.5 10818 0 10825 5 10830 0 10831 5 10843 0 10849 0 10852 5 10858 0 10873 0 10881 5 10890.0 10908.0 10909.0 10911.5 10913.0 10915.0 10917.5 10924.0 10934 0 10937 5 10949 0 10962 0 10974 5 10976 0 10986 0 11013 5 11016 5 11019 5 11037 0 11039 0 11044 0 11068 0 11071 5 11073 5 11075 5 11079 5 11084 0 11158 5 11173 5 11179 5 11187 5 11195 5 11198 0 11209 5 11210.5 11219.5 11231.5 11237.0 11240.0 11241.0 11244 0 11247 0 11250 5 11251 5 11258 0 11269 0 11274 5 11276 5 11280 5 11282 0 11290 0 11294 0 11296 0 11301 0 11304 5 11314 0 11339 5 11372 0 11379 0 11384 5 11387 0 11404 0 11408 5 11410 0 11415 5 11425.5 11430.5 11432.5 11439.0 11441.0 11474.5 11482.0 11492.5 11494 5 11502 0 11513 0 11529 5 11534 0 11538 0 11544 5 11553 0 11560 5 11566.5 11568.0 11570.0 11577.5 11582 0 11601 5 11614 0 11617 5 11655 0 11667 0 11673 5 11677 5 11682 0 11684 0 11693 5 11696 5 11701 0 11703 5 11718 5 11727 0 11211 0 11219 0 11229 5 11235 0 11237 0 11238 5 11243 0 11245 5 11249 5 11251 0 11258 0 11267 5 11272 0 11275 5 11280 0 11281.0 11290.0 11295.0 11297.5 11300.5 11304.0 11313.0 11337.5 11372 .0 11380.0 11384.5 11387.0 11403.0 11408.5 11409.5 11416.0 11427.0 11433.0 11434.5 11440.5 11443.0 11479.0 11485.5 11493,5 11496.0 11504.0 11515.0 11531.5 11535.5 11541.0 11547.5 11556.5 11563 .0 11568,5 11571.0 11572 5 11580 5 11584 5 11603 5 11617 0 11619 5 11656 5 11666 0 11672 0 11675 5 11680 5 11682 5 11694 5 11698 5 11700 5 11703 0 11717 5 11728 5 RECEiVeD .pR 24 2000 ,6J88ka 0il & G~$ Cons. Commirmion AnotlOf~,§e 11729.5 11730.0 11733.0 11733.0 11860.0 11860.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 9670.5 10010.5 10011.0 10230.0 10230.5 11860.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9673 11860 10766.5 4375 ROP MWD FT/H 0 142.89 38.6534 4319 GR MWD API 13.46 152.72 60.7576 4294 First Reading 9673 9701 9673 Last Reading 11860 11860 11819.5 First Reading For Entire File .......... 9673 Last Reading For Entire File ........... 11860 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record PILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9670.5 ROP 9698.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9982.5 10010.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MF~ASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MI/D CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined 17-0CT-99 Insite 0 Memory 10010.0 39.6 57.2 TOOL NUMBER GM 72829 4.750 9673.0 QuIKDRIL-N 8.40 46.0 9.0 1300 10.9 .000 .000 .000 .000 .0 115.0 .0 .0 Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9670.5 10010.5 9840.5 681 ROP MWD020 FT/H 0 75.08 34.5033 625 GR MWD020 API 13.46 142.28 36.5594 625 First Reading 9670.5 9698.5 9670.5 Last Reading 10010.5 10010.5 9982.5 First Reading For Entire File .......... 9670.5 Last Reading For Entire File ........... 10010.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RD-N NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9983 . 0 10201 . 5 ROP 10011 . 0 10230 . 0 $ LOG HEADER DATA DATE LOGGED: 19-0CT-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 10230.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIM UMANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE~ MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 64.1 89.3 TOOL NUMBER GM 72829 4.750 QUI~RIL-N 8.40 47.0 9.6 1500 9.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 .0 169.0 .0 .0 LPR 24 2000 aJa.$ka 0~1 & Gas r',,,:,- Commission Anchoraoje Name Service Unit Min Max Mean Nsam DEPT FT 9983 10230 10106.5 495 ROP MWD030 FT/H 1.62 120.14 25.8773 439 GR MWD030 API 27.36 142.8 63.065 438 First Last Reading Reading 9983 10230 10011 10230 9983 10201.5 First Readin9 For Entire File .......... 9983 Last Reading For Entire File ........... 10230 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10202.0 ROP 10230.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11819.5 11860.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 25-0CT-99 Insite 0 Memory 11860.0 86.3 94.5 TOOL NUMBER GM 74165 4.750 QUIKDRIL-N 8.40 47.0 9.3 1400 7.6 .000 .000 .0 135.0 MLrD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 10202 11860 11031 3317 ROP MWD040 FT/H 0 142.89 41.1481 3260 GR MWD040 API 43.77 152.72 64.7922 3236 First Reading 10202 10230.5 10202 Last Reading 11860 11860 11819.5 First Reading For Entire File .......... 10202 Last Reading For Entire File ........... 11860 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/04/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/04/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE APR 24 2000 An.chorege Scientific Technical Services Date ..................... 00/04/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Wednesday, December 27, 2023 8:41 AM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); PB Wells Integrity; Bo York; Oliver Sternicki Subject:NOT OPERABLE: Producer 02-27A (PTD #1990930) Tubing Leak Mr., Regg, A tubing tail plug was set at 8587’ MD on 12/25/23 and the well passed a CMIT‐TxIA to 2348 psi on 12/26/23, but we were unable to get a passing MIT‐T. Follow‐up slickline work found a suspected leak in the vicinity of GLM#1 at 8524’ MD. The well is now classified as NOT OPERABLE and will remain shut‐in unƟl the tubing barrier is restored. Please respond with any quesƟons. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, December 8, 2023 2:06 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer 02‐27A (PTD #1990930) anomalous IA re‐pressurization above MOASP Mr. Regg, Producer 02‐27A (PTD #1990930) is currently UNDER EVALUATION for anomalous IA re‐pressurizaƟon. On 12/07 the well was shut‐in to for slickline to perform GLV work and the IAP exceeded MOASP. The reported IA pressure was 2,142 psi. This noƟficaƟon is to saƟsfy the reporƟng requirements outlined in CO 492. The well is currently on day 8 of a 28‐ day clock to resolve the issue. Plan forward: 1. Slickline: Set GL re‐design 2. DHD: TIFL 3. Well Integrity: AddiƟonal diagnosƟcs as needed Please respond with any quesƟons. Andy Ogg CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. 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